CALGARY, May 6, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, OTCQB – OBEL) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce our first quarter 2020 financial and operational results. All figures are in Canadian dollars unless otherwise stated. Obsidian Energy's unaudited interim consolidated financial statements and Management's Discussion and Analysis ("MD&A") as at and for the three months ended March 31, 2020 can be found on our website at www.obsidianenergy.com. The documents will also be filed on SEDAR and EDGAR in due course.
FINANCIAL AND OPERATING HIGHLIGHTS
Three months ended March 31 | ||||||||||
2020 | 2019 | |||||||||
FINANCIAL1 (millions, except per share amounts) | ||||||||||
Cash flow from Operations | $ | 33 | $ | (1) | ||||||
Basic and Diluted ($/share) | 0.45 | (0.01) | ||||||||
Funds Flow from Operations 2 | 37 | 36 | ||||||||
Basic and Diluted ($/share) | 0.51 | 0.50 | ||||||||
Net loss | (746) | (54) | ||||||||
Basic and Diluted ($/share) | (10.22) | (0.74) | ||||||||
Capital expenditures | 41 | 34 | ||||||||
Decommissioning expenditures | 8 | 2 | ||||||||
Net Debt 2 | $ | 517 | $ | 497 | ||||||
Average sales price 3 | ||||||||||
Light oil ($/bbl) | $ | 50.59 | $ | 64.88 | ||||||
Heavy oil ($/bbl) | 20.07 | 30.62 | ||||||||
NGL ($/bbl) | 22.52 | 21.44 | ||||||||
Natural gas ($/mcf) | $ | 2.20 | $ | 2.41 | ||||||
Netback 2 ($/boe) | ||||||||||
Sales price | $ | 32.17 | $ | 39.95 | ||||||
Risk management gain (loss) | 4.47 | (1.80) | ||||||||
Net sales price | 36.64 | 38.15 | ||||||||
Royalties | (2.23) | (2.81) | ||||||||
Operating expenses 4 | (12.04) | (13.49) | ||||||||
Transportation | (2.68) | (2.87) | ||||||||
Netback 2 ($/boe) | $ | 19.69 | $ | 18.98 | ||||||
OPERATIONS | ||||||||||
Daily Production | ||||||||||
Light oil (bbls/d) | 12,512 | 12,376 | ||||||||
Heavy oil (bbls/d) | 3,644 | 4,096 | ||||||||
NGL (bbls/d) | 2,239 | 2,122 | ||||||||
Natural gas (mmcf/d) | 52 | 54 | ||||||||
Total production 5 (boe/d) | 27,092 | 27,651 |
(1) | Effective June 5, 2019, the Company consolidated its common shares based on seven old common shares outstanding for one new common share. All figures in the table have been updated to reflect the 7:1 consolidation. |
(2) | The terms Funds Flow from Operations ("FFO") and their applicable per share amounts, "Net Debt", and "Netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(3) | Before risk management gains/(losses). |
(4) | Includes the benefit of processing fees totaling $2 million for 2020 (2019 - $2 million). |
(5) | Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
MESSAGE TO SHAREHOLDERS
Obsidian Energy had a successful operational and financial start to the year, yielding strong results for the first quarter and achieving a number of significant operational and financial milestones. As previously announced, the Company successfully renegotiated the terms of our syndicated credit facility, senior notes and Calgary office lease at the end of the quarter which will provide the Company with additional go-forward financial flexibility. Operationally our team completed a successful ten well drilling program, with some of the strongest initial rates we have seen to date in our multi-year Cardium program. The full effect of the cost saving initiatives implemented throughout 2019 were demonstrated by the 19% decrease in general and administrative costs and the 11% decrease in operating costs from the first quarter of 2019. These efforts better position the Company to help withstand the market volatility at this crucial time for our industry.
The demand destruction caused by the COVID-19 global pandemic and the potential supply increase from the OPEC+ price war has caused a significant decrease in oil prices and Obsidian Energy has reacted quickly to this significant change in market conditions. At this time, our plan is to significantly limit further capital spending for the foreseeable future, temporarily shut-in uneconomic production and to continue to optimize all aspects of our business to reduce costs and maintain financial liquidity during this challenging time. The Board of Directors and executive team implemented a temporary salary reduction of 20% across all head office staff and a 10% reduction for field staff. In addition, the Company has suspended the employer contributions to the Employee Retirement Savings Plan and the Board of Directors have taken a temporary 10% reduction on their annual retainer fees. These initiatives have reduced operating costs by over $8 million and personnel costs by approximately $10 million if annualized.
The Company has applied for the Canadian Emergency Wage Subsidy (CEWS), a program announced by the federal government in which eligible companies may receive a subsidy of 75% of employee wages (up to a cap) for up to 12 weeks, applicable from March 15, 2020, to June 6, 2020. We have also applied for support under the Alberta Site Rehabilitation Program through our service providers. This program, which is primarily funded by the federal government's COVID-19 Economic Response Plan, is expected to further allow the Company to continue well, pipeline, and infrastructure abandonment and reclamation projects by providing grants directly to service companies. Applications for these grants are subject to certain maximums and may be eligible for up to 100 per cent government funding. We will continue to watch for further details of all federal government support packages available to the Company and will seek further support as appropriate.
Operationally the Company continues to conduct detailed evaluations of our producing assets and will shut-in production where economic thresholds are not met. As of May 1, 2020, the Company has shut-in 3,784 boe/d across its properties, predominantly within our Peace River heavy oil asset. Shut-ins are being conducted in a manner that will allow production to be restarted in an efficient manner as oil prices recover.
FIRST QUARTER RESULTS
Production Volumes by Product and Producing Region – Three Months Ended March 31, 2020 | |||||
Area | Production (boe/d) | Light Oil (bbls/d) | Heavy Oil (bbls/d) | NGLs (bbls/d) | Gas (mmcf/d) |
Cardium | 21,739 | 12,197 | 40 | 2,168 | 44 |
Alberta Viking | 830 | 219 | 44 | 37 | 3 |
Peace River | 4,040 | - | 3,432 | 3 | 4 |
Key Development Areas | 26,609 | 12,416 | 3,516 | 2,208 | 51 |
Legacy Areas | 483 | 96 | 128 | 31 | 1 |
Key Development & Legacy Areas | 27,092 | 12,512 | 3,644 | 2,239 | 52 |
Operating Cost and Netbacks by Producing Region – Three Months Ended March 31, 2020 | ||
Area | Operating Cost ($/boe) | Netback(1) ($/boe) |
Cardium | 9.63 | 21.51 |
Alberta Viking | 14.41 | 8.02 |
Peace River | 15.73 | (4.84) |
Key Development Areas | 10.71 | 17.09 |
Legacy Areas | 50.69 | (28.73) |
Key Development & Legacy Areas | 12.04 | 15.23 |
(1) | Netback excludes risk management gains. |
2020 DEVELOPMENT PROGRAM AND OPERATIONS UPDATE
As previously announced in our Corporate and Operational update dated April 23, 2020, Obsidian Energy completed its first half capital program successfully and safely in the first quarter. All ten completed wells are on production or are ready to produce as pricing improves. Wells with production rates in the table below are currently producing.
Well | Status |
02/04-28-043-08W5 (12-26 Pad) | IP30: 1,012 boe/d (73% light oil) |
00/09-28-043-08W5 | IP30: 925 boe/d (72% light oil) |
00/14-28-043-08W5 | IP30: 1,145 boe/d (75% light oil) |
00/05-15-043-08W5 (1-27 Pad) | Ready to produce |
00/15-16-043-08W5 | Ready to produce |
00/02-30-042-07W5 (3-6 Pad) | IP30: 692 boe/d (89% light oil) |
00/03-30-042-07W5 | IP30: 363 boe/d (89% light oil) |
00/02-08-042-07W5 (14-17 Pad) | IP10: 163 boe/d (90% light oil) |
00/04-30-042-07W5 | IP10: 245 boe/d (90% light oil) |
00/15-32-042-07W5 (3-29 Pad) | IP30: 443 boe/d (90% light oil) |
In response to the volatility of commodity prices amid the COVID-19 pandemic, all previously announced shut-ins were completed by May 1, 2020 as follows:
Area | Production (boe/d) | Light Oil (bbl/d) | Heavy Oil (bbl/d) | NGLs (bbls/d) | Gas (mcf/d) |
Cardium | 576 | 438 | - | 23 | 692 |
Alberta Viking | 144 | - | 130 | - | 81 |
Peace River | 3,064 | - | 2,538 | 2 | 3,148 |
Total | 3,784 | 438 | 2,668 | 25 | 3,921 |
Obsidian Energy continues to monitor the commodity price environment and evaluate our portfolio to improve the overall financial flexibility of the business. The Company is prepared to take further action to shut-in additional production should oil prices not improve in the near term. Alternatively, we can quickly restart shut-in production once oil prices permit doing so. Our current first half 2020 guidance is provided below. Given the current volatility in the commodity markets we are not providing full year guidance at this time. We will provide updates as further production or financial decisions are implemented.
First Half 2020 Production and Cost Guidance | ||
Metric | Guidance Range | |
Production (boe/d) 1 2 3 | 25,500 – 26,000 | |
Capital Expenditures ($millions) | 43 | |
Decommissioning Expenditures ($millions) | 8 | |
Operating Costs ($/boe) | 11.50 – 11.90 | |
General & Administrative ($/boe) | 1.65 – 1.85 | |
(1) | Adjusted for January 2020 Carrot Creek Disposition of 115 boe/d (85% light oil) |
(2) | Previous guidance included 600 boe/d of shut-in production |
(3) | Mid-point of guidance 12,500 bbls/d light oil, 2,500 bbls/d heavy oil, 2,200 bbls/d NGLs and 51 mmcf/d natural gas |
2020 HEDGING PROGRAM
In 2020, the Company has the following hedges in place:
April | May | June | |||
WTI (C$/bbl) | 78.11 | 77.92 | 77.41 | ||
Total (bbl/day) | 4,000 | 3,000 | 2,000 | ||
Q2 | Q3 | ||||
(C$/GJ) | 1.59 | 1.60 | - | ||
Total (GJ/day) | 25,000 | 24,000 | - |
ANNUAL GENERAL MEETING
The Company is pleased to announce that its Annual General Meeting ("AGM") will be scheduled for Thursday, July 30, 2020 at 10:00 am (Mountain Time), pursuant to the extension granted by the Toronto Stock Exchange. It is our intention to hold our AGM in person at the offices of Obsidian Energy depending on the Alberta Health guidelines in place on public gatherings at that time, and therefore the Company is reserving the right to restrict access to our AGM and/or conduct the AGM in a virtual format. Further announcements and information regarding the AGM will be made in due course. In addition, all information and documents that would normally be filed or delivered by the Company in connection with our AGM, including but not limited to our annual and interim request forms and executive compensation disclosure, will be delayed until the dissemination of our AGM materials on or about June 30, 2020, pursuant to exemptions provided by applicable securities regulators, including Alberta Securities Commission Blanket Order 51-518.
UPDATED CORPORATE PRESENTATION
For further information on these and other matters, Obsidian Energy has posted an updated Corporate Presentation which can be found on its website, www.obsidianenergy.com.
ADDITIONAL READER ADVISORIES
OIL AND GAS INFORMATION ADVISORY
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
NON-GAAP MEASURES
Certain financial measures including FFO, FFO per share-basic, FFO per share-diluted, netback and net debt, included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. FFO is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures, office lease settlements, the effects of financing related transactions from foreign exchange contracts and debt repayments and certain other expenses and is representative of cash related to continuing operations. FFO is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of FFO to cash flow from operating activities, being its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation expenses and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. Net debt is the total of long-term debt and working capital deficiency and is used by the Company to assess its liquidity.
CALCULATION OF FUNDS FLOW FROM OPERATIONS
Three months ended March 31 | |||||
(millions, except per share amounts) | 2020 | 2019 | |||
Cash flow from operating activities | $ | 33 | $ | (1) | |
Change in non-cash working capital | (5) | 27 | |||
Decommissioning expenditures | 8 | 2 | |||
Onerous office lease settlements | (1) | 1 | |||
Restructuring charges | - | 1 | |||
Other expenses 1 | 2 | 6 | |||
Funds flow from operations | $ | 37 | $ | 36 | |
Per share – funds flow from operations | |||||
Basic and diluted per share | $ | 0.51 | $ | 0.50 |
(1) | Includes legal fees related to claims against former Penn West Petroleum Ltd. ("Penn West") employees related to the Company's 2014 restatement of certain financial results. |
ABBREVIATIONS
Oil | Natural Gas | ||
Bbl | barrel or barrels | GJ | Gigajoule |
bbl/day | barrels per day | GJ/day | gigajoule per day |
boe/d | barrels of oil equivalent per day | mmcf | million cubic feet |
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the unaudited interim consolidated financial statements and MD&A will be filed in due course on SEDAR and EDGAR; the culmination of costs savings from 2019 and through 2020 to date better position the Company to help withstand the market volatility at this crucial time for our industry; that the Company plans to significantly limit further capital spending for the foreseeable future, temporarily shut-in production and to continue to optimize all aspects of our business to reduce costs and maintain financial liquidity during this challenging time; that the Alberta Site Rehabilitation Program, is expected to further allow the Company to continue well, pipeline, and infrastructure abandonment and reclamation projects by providing grants directly to service companies, which will be subject to certain maximums and may be eligible for up to 100 percent of government funding; that we will continue to watch for further details of all federal government support packages available to the Company and will seek further support as appropriate; that the Company will shut-in production where economic thresholds are not met and for those that are shut-in, that they are being suspended in such a way that will allow production to be restarted in an efficient manner as oil prices recover; that impairment losses related to PP&E can be reversed in future periods if commodity prices forecasts improve; our first half guidance including production, capital and decommissioning expenditures, operating and general and administrative costs; and that we will provide updates as further production or financial decisions are implemented; and the date of our AGM, when the applicable materials can be expected for it and how the meeting will be conducted.
With respect to forward-looking statements contained in this document, the Company has made assumptions regarding, among other things: we will have the ability to continue as a going concern going forward and realize our assets and discharge our liabilities in the normal course of business; that the Company does not dispose of or acquire material producing properties or royalties or other interests therein; the impact of the Alberta government mandated curtailment of crude oil and bitumen production; the impact of regional and/or global health related events, including the ongoing COVID-19 pandemic, on energy demand; that the Company's operations and production will not be disrupted by circumstances attributable to the COVID-19 pandemic and the responses of governments and the public to the pandemic; global energy policies going forward, including the continued agreement of members of OPEC, Russia and other nations to adhere to existing production quotas or further reduce production quotas; our ability to qualify for government programs created as a result of the COVID-19 pandemic and obtain financial assistance therefrom and the impact of those programs on our financial condition; our ability to execute our plans as described herein and in our other disclosure documents and the impact that the successful execution of such plans will have on our Company and our stakeholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels, including that we will not be required to shut-in additional production due to the continuation of low commodity prices or the further deterioration of commodity prices and our expectations regarding when commodity prices will improve such that shut-in properties can be returned to production; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, wild fires, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including that the revolving period and term out period of our credit facility are not accelerated, that the maturity date of our senior notes is not accelerated, that our borrowing base is not decreased under our credit facility, our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although the Company believes that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we are not able to continue as a going concern and realize our assets and discharge our liabilities in the normal course of business; the possibility that the Company will not be able to continue to successfully execute our business plans and strategies in part or in full, and the possibility that some or all of the benefits that the Company anticipates will accrue to our Company and our stakeholders as a result of the successful execution of such plans and strategies do not materialize; the possibility that the Company is unable to complete one or more of the potential transactions being pursued pursuant to our ongoing strategic alternatives review process, including the potential disposition of assets, on favorable terms or at all; the possibility that the Company does not qualify for one or more government assistance programs implemented in connection with the COVID-19 pandemic and other regional and/or global health related events, or that the impact of such programs falls below our expectations; the impact on energy demand of regional and/or global health related events, including the ongoing COVID-19 pandemic and the responses of governments and the public to the pandemic, including the risk that the amount of demand destruction and/or the length of the decreased demand exceeds or expectations; the possibility that the revolving period and term out period of our credit facility and the maturity date of our senior notes is accelerated, that the borrowing base under our credit facility is reduced, that the Company is unable to renew our credit facilities on acceptable terms or at all and/or finance the repayment of our senior notes when they mature and/or obtain debt and/or equity financing to replace one or both of our credit facilities and senior notes; the possibility that we breach one or more of the financial covenants pursuant to our agreements with our lenders and the holders of our senior notes; the possibility that we are forced to shut-in additional production or continue existing production shut-ins longer than anticipated, whether due to commodity prices failing to rise or decreasing further or changes to existing government curtailment programs or the imposition of new programs; the risk that OPEC, Russia and other nations fail to adhere to existing production quotas or agree to new production quotas to balance supply and demand fundamentals for crude oil; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, April 23, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX: OBE, OTCQB: OBEL) ("Obsidian Energy", the "Company", "we", "us" or "our") has taken further proactive action to shut-in currently uneconomic production with a focus on preserving its balance sheet and improving financial flexibility. Additionally, the Company releases the date of its first quarter 2020 results.
Production Shut-In Program & Operational Update
Obsidian Energy's operations are very flexible and allow the Company to respond quickly to the current commodity price environment by shutting-in production at minimal cost without risk of long-term reservoir impairment. In order to improve the ongoing business performance of the Company in these conditions, the following volumes will be shut in by May 1, 2020:
Area | Production | Light Oil | Heavy Oil | NGLs | Gas |
Cardium | 576 | 438 | - | 23 | 692 |
Alberta Viking | 144 | - | 130 | - | 81 |
Peace River | 3,064 | - | 2,538 | 2 | 3,148 |
Total | 3,784 | 438 | 2,668 | 25 | 3,921 |
Given the current volatility in oil prices, Obsidian Energy is prepared to take further action to shut-in additional production should oil prices not improve in the near term. Alternatively, we can quickly restart shut-in production once oil prices permit doing so. We will further update our guidance should any of those decisions be implemented.
The Company's capital program for the first half of 2020 has been successfully and safely completed. All ten development wells drilled in our program are on production or are ready to produce as desired by the Company. As with our base production, our new wells are highly tolerant of temporary production shut-ins and volumes can be adjusted or curtailed as pricing conditions warrant.
Pad | Status (average production per well) |
12-26 Pad (3 wells) | IP10: 1,215 boe/d (82% light oil) IP30: 1,035 boe/d (74% light oil) (2 of 3 wells at 30 days) |
1-27 Pad (2 wells) | Ready to produce |
3-6 Pad (2 wells) | IP10: 493 boe/d (90% light oil) IP30: 526 boe/d (89% light oil) |
14-17 Pad (2 wells) | Producing as of April 20. |
3-29 Pad (1 well from existing pad) | IP10: 587 boe/d (90% light oil) |
First Half 2020 Production and Cost Guidance
As a result of these production shut-in decisions, and our continued and extensive focus on cost reductions, further development drilling in 2020 has been deferred until pricing conditions justify the investment. In addition, since the beginning of 2020 we have successfully removed costs across several areas, including (prior to any shut-in production) an additional $8 million from our original operating cost estimate for the first half of the year due to increased efficiencies and reduced production volumes.
Metric | Previous Guidance | Updated Guidance |
Production (boe/d)1 2 3 | 26,500 – 27,100 | 25,500 – 26,000 |
Capital Expenditures ($millions) | 46 | 43 |
Decommissioning Expenditures ($millions) | 8 | 8 |
Operating Costs ($/boe) | 11.90 – 12.30 | 11.50 – 11.90 |
General & Administrative ($/boe) | 1.70 – 1.90 | 1.65 – 1.85 |
(1) | Adjusted for January 2020 Carrot Creek Disposition of 115 boe/d (85% light oil) |
(2) | Previous guidance included 600 boe/d of shut-in production |
(3) | Mid-point of guidance 12,500 bbls/d light oil, 2,500 bbls/d heavy oil, 2,200 bbls/d NGLs and 51,000 mcf/d natural gas |
First Quarter 2020 Results Date
Obsidian Energy is expected to release its first quarter 2020 financial and operational results before North American markets open on Wednesday, May 6, 2020. In addition, the first quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on or about the same date.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and/or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this presentation contains, without limitation, forward-looking statements pertaining to the following: our focus on preserving our balance sheet and improving financial flexibility with our shut-in program; that we have flexible operations which allows the Company to respond quickly to the current commodity price environment by shutting-in production at minimal cost without risk of long-term reservoir impairment; which volumes will be shut-in by May 1, 2020; that we are prepared to take further action to shut-in additional production should oil prices not improve in the near term or that we can quickly restart shut-in production once oil prices permit doing so and that we will further update our guidance should any of those decisions be implemented; that our new wells are highly tolerant of temporary production shut-ins and volumes can be adjusted or curtailed as pricing conditions warrant; that further development drilling in 2020 has been deferred until pricing conditions justify the investment; our updated guidance for production, capital and decommissioning expenditures, and operating and general and administrative costs; and when and where we expect to release our first quarter 2020 financial and operational results as well as the other associated documents.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: we will have the ability to continue as a going concern going forward and realize our assets and discharge our liabilities in the normal course of business; our ability to complete asset sales and the terms and timing of any such sales; the Alberta government mandated production curtailment; the impact of regional and/or global health related events on energy demand; global energy policies going forward; the economic returns that we anticipate realizing from expenditures made on our assets; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future capital expenditure levels; future crude oil, natural gas liquids and natural gas production levels; drilling results; future exchange rates and interest rates; future taxes and royalties; the continued suspension of our dividend; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully; our ability to obtain financing on acceptable terms, including our ability to renew or replace our reserve based loan; that we are able to move forward through the various reconfirmation, redetermination dates with the credit facility and our ability to finance the repayment of our senior secured notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although Obsidian Energy believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Obsidian Energy can give no assurances that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to: the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; the possibility that the semi-annual borrowing base re-determination under our reserve-based loan is not acceptable to the Company or that we breach one or more of the financial covenants pursuant to our amending agreements with holders of our senior secured notes; the impact that any government assistance programs could have on the Company in connection with, among other things, the COVID-19 pandemic and other regional and/or global health related events; the possibility that we are not able to continue as a going concern and realize our assets and discharge our liabilities in the normal course of business; the impact on energy demands due to regional and/or global health related events; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; interest rate fluctuations; marketing and transportation; loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; reliance on third parties; and changes in legislation, including but not limited to tax laws, royalties and environmental regulations. Readers are cautioned that the foregoing list of factors is not exhaustive. Additional information on these and other factors that could affect Obsidian Energy, or its operations or financial results, are included in the Company's Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) which may be accessed through the SEDAR website (www.sedar.com), EDGAR website (www.sec.gov) or Obsidian Energy's website.
Unless otherwise specified, the forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward.
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SOURCE Obsidian Energy Ltd.
CALGARY, April 1, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") received notification from the New York Stock Exchange (the "NYSE") that the Company has not regained compliance with the NYSE's continued listing standard regarding share price pursuant to Rule 802.01C of the NYSE's Listed Company Manual. As a result, OBE.BC shares have been suspended from trading on the NYSE effective immediately. To facilitate trading for our United States based shareholders, Obsidian Energy's common shares will begin trading on the OTCQB under the symbol OBELF on April 2, 2020 and will remain trading on the Toronto Stock Exchange under the symbol OBE.
The significant change in the macro economic environment has contributed to a reduction in the Company's share price. If our share price improves to average over US$0.25 per share for 30 consecutive days, we will move to the OTCQX market. The move in listing from the NYSE to the OTCQB is expected to result in on-going cost savings of approximately $1 million per year at this time. The transition to the OTC markets will not affect the Company's business operations or our current Securities and Exchange Commission reporting obligations and does not conflict with or cause an event of default under any of the Company's material debt or other agreements.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, that the Common Shares will commence trading on the OTCQB on April 2, 2020 and will remain trading on the Toronto Stock Exchange under the symbol OBE; that if our share price improves to average over US$0.25 per share for 30 consecutive days, we will move to the OTCQX market; the expected costs saving to the Company by moving to the OTCQB; and that the OTC markets will not affect the Company's business operations or our current Securities and Exchange Commission reporting obligations and does not conflict with or cause an event of default under any of the Company's material debt or other agreements.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward‑looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, March 30, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", "we", "us" or "our") announces that we have filed with Canadian securities regulatory authorities our audited Consolidated Financial Statements for the year ended December 31, 2019 and related Management's Discussion and Analysis. Obsidian Energy has also filed our Annual Information Form for the year ended December 31, 2019, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101. Obsidian Energy's Annual Report on Form 40-F for the year ended December 31, 2019 has been filed with the U.S. Securities and Exchange Commission pursuant to its rules and regulations.
Copies of these documents may be obtained electronically via www.sedar.com and www.sec.gov/edgar.shtml (for the Form 40-F) or through Obsidian Energy's website at www.obsidianenergy.com. Hard copies of Obsidian Energy's audited Consolidated Financial Statements and related MD&A are also available upon request, free of charge, by contacting our Investor Relations group or by requesting them through our website.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and on the New York Stock Exchange under the symbol "OBE.BC".
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SOURCE Obsidian Energy Ltd.
Met or Exceeded all 2019 Guidance Metrics
Achieved Significant Reduction in Undiscounted Asset Retirement Obligations During 2019
Strong Continued Operational and Development Results Year to Date
CALGARY, March 30, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce our year-end 2019 financial and operational results, development program updates, and an update on our US listing. All figures are in Canadian dollars unless otherwise stated. Obsidian Energy's audited consolidated financial statements and Management's Discussion and Analysis ("MD&A") as at and for the year-ended December 31, 2019 can be found on our website at www.obsidianenergy.com. The documents will also be filed on SEDAR and EDGAR in due course.
FINANCIAL AND OPERATING HIGHLIGHTS
Three months ended December 31 | Year ended December 31 | |||||||||
2019 | 2018 | 2019 | 2018 | |||||||
FINANCIAL1 (millions, except per share amounts) | ||||||||||
Cash flow from Operations | 49 | 19 | 77 | 99 | ||||||
Basic and Diluted ($/share) | 0.67 | 0.26 | 1.06 | 1.36 | ||||||
Funds Flow from Operations2 | 54 | (2) | 160 | 92 | ||||||
Basic and Diluted ($/share) | 0.74 | (0.03) | 2.20 | 1.26 | ||||||
Net loss | (544) | (113) | (788) | (305) | ||||||
Basic and Diluted ($/share) | (7.45) | (1.56) | (10.81) | (4.22) | ||||||
Capital expenditures | 34 | 41 | 103 | 168 | ||||||
Net Debt2 | 495 | 497 | 495 | 497 | ||||||
Average sales price3 | ||||||||||
Light oil ($/bbl) | 70.57 | 37.88 | 68.99 | 66.60 | ||||||
Heavy oil ($/bbl) | 41.80 | 7.70 | 38.82 | 33.07 | ||||||
NGL ($/bbl) | 31.42 | 24.99 | 20.77 | 36.69 | ||||||
Natural gas ($/mcf) | 2.55 | 2.46 | 1.79 | 2.21 | ||||||
Netback2 ($/boe) | ||||||||||
Sales price | 45.67 | 23.42 | 41.60 | 39.45 | ||||||
Risk management gain (loss) | 0.66 | (3.84) | (0.66) | (6.10) | ||||||
Net sales price | 46.33 | 19.58 | 40.94 | 33.35 | ||||||
Royalties | (3.79) | (2.33) | (3.11) | (3.40) | ||||||
Operating expenses4 | (12.75) | (11.82) | (13.42) | (13.89) | ||||||
Transportation | (2.56) | (3.45) | (2.76) | (3.39) | ||||||
Netback2 ($/boe) | 27.23 | 1.98 | 21.65 | 12.67 | ||||||
OPERATIONS | ||||||||||
Daily Production | ||||||||||
Light oil (bbls/d) | 12,246 | 11,429 | 11,966 | 11,342 | ||||||
Heavy oil (bbls/d) | 3,718 | 4,784 | 3,965 | 4,885 | ||||||
NGL (bbls/d) | 2,095 | 2,788 | 2,153 | 2,410 | ||||||
Natural gas (mmcf/d) | 52 | 65 | 53 | 62 | ||||||
Total production5 (boe/d) | 26,639 | 29,905 | 26,901 | 28,953 |
(1) | Effective June 5, 2019, the Company consolidated its common shares based on seven old common shares outstanding for one new common share. All figures in the table have been updated to reflect the 7:1 consolidation. |
(2) | The terms Funds Flow from Operations ("FFO") and their applicable per share amounts, "Net Debt", and "Netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(3) | Before risk management gains/(losses). |
(4) | Includes the benefit of processing fees totaling $8 million for 2019 (2018 - $11 million). |
(5) | Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
MESSAGE TO SHAREHOLDERS
We are pleased to announce our full year 2019 operating and financial results which met or exceeded our 2019 guidance metrics. Our 2019 average production was 26,901 boe/d, within our guidance range of 26,750 to 27,250 boe/d. We came in below guidance on capital, operating and general and administrative expenses as a result of several efficiencies, specifically cost reduction and restructuring initiatives that took place throughout the year.
Our capital execution was strong in 2019, as we continued to build on our success in the Willesden Green area of the Cardium, with the drilling of 19 net operated Cardium locations (96% working interest). These wells delivered strong initial rates and continue to produce as expected (IP60: 385 boe/d, 79% light oil per well). Our capital expenditures were $103 million, below our guidance of $108 million, as we were successful in reducing our costs per well to $3.7 million for the year – averaging $3.5 million for the second half of the year – with an average horizontal length of over 2,630 meters. These costs are inclusive of all construction, drilling, completions, equipping, and gathering system expenditures.
We made significant progress in the management of our decommissioning liabilities. In 2019 we participated in the AER's Area Based Closure ("ABC") program, which allowed the Company to efficiently deliver 189 net well abandonments and 1,139 km of pipeline abandonments. Through completed work, asset divestitures, and using information obtained from government estimates and internal analysis, our undiscounted asset retirement obligation ("ARO") liability at year-end 2019 was reduced by 27% to $621 million from $847 million.
The Company met or exceeded all key performance targets in 2019 as we continued to focus on development execution and completed numerous cost reduction initiatives.
Metric | 2019 Guidance Range | 2019 Results |
Production1 (boe/d) | 26,750 to 27,250 | 26,901 |
Capital Expenditures ($millions) | 108 | 103 |
Decommissioning Expenditures ($millions) | 12 | 14 |
Operating Costs ($/boe) | 13.50 - 13.75 | 13.42 |
General & Administrative ($/boe) | 2.10 to 2.35 | 2.03 |
(1) | See production and highlights table for production details |
This momentum has carried into the first quarter of 2020 in which we have successfully completed 10 new Willesden Green Cardium wells, including wells with the best initial rates recorded to-date in the program.
Moving forward into 2020 there are several significant improvements to the underlying business which will result in positive go-forward benefits to cash flow:
STRONG FOURTH QUARTER AND FULL YEAR RESULTS
Production Volumes by Product and Producing Region – Three Months Ended December 31, 2019 | ||||||
Area | Production | Light Oil | Heavy Oil | NGLs (bbls/d) | Gas | |
Cardium | 20,950 | 11,782 | 28 | 2,041 | 43 | |
Alberta Viking | 849 | 205 | 45 | 27 | 4 | |
Peace River | 4,230 | 70 | 3,487 | 4 | 4 | |
Key Development Areas | 26,029 | 12,057 | 3,560 | 2,072 | 51 | |
Legacy Areas | 610 | 189 | 158 | 23 | 1 | |
Key Development & Legacy Areas | 26,639 | 12,246 | 3,718 | 2,095 | 52 |
Operating Cost and Netbacks by Producing Region – Three Months Ended December 31, 2019 | |||
Area | Operating Cost ($/boe) | Netback ($/boe) | |
Cardium | 12.45 | 29.13 | |
Alberta Viking | 12.17 | 16.26 | |
Peace River | 10.22 | 21.06 | |
Key Development Areas | 12.08 | 27.39 | |
Legacy Areas | 41.12 | (8.64) | |
Key Development & Legacy Areas | 12.75 | 26.57 |
2020 DEVELOPMENT AND ENVIRONMENTAL PROGRAM UPDATE
At the end of the first quarter of 2020, we are experiencing significant volatility in global oil markets due to OPEC and Russia abandoning quotas and increasing production levels, significant demand destruction as a result of the global spread of the COVID-19 virus and, potential lack of storage forcing production shut-ins. At the time oil prices fell sharply, Obsidian Energy had executed the vast majority of our first quarter drilling program, which is now completed. We have flexibility in our portfolio to manage remaining capital expenditures through the balance of 2020 with a view to preserving liquidity and long-term shareholder value. If the current oil price environment continues, we anticipate no development capital spending for the balance of 2020.
Early in the first quarter, given initially strong oil prices, we advanced our capital plans which increased our forecasted first half spend to $54 million, including a production-efficient optimization program of $4 million and decommissioning expenditures of $8 million. This plan included the rig-release of nine wells in the Willesden Green area, completion of ten wells (including our additional December 2019 drill), and acceleration of 2020 decommissioning activity to address well sites that require frozen conditions for efficient abandonment.
Our operations in the first quarter have proceeded on schedule and within our cost estimates, despite the severe cold encountered during the month of January. Drilling and completions activities have finished successfully, with production from all new wells anticipated to be fully online in April, subject to any commodity price related curtailment we implement. Early deliverability results from the first five wells to date have been particularly strong, with initial results significantly exceeding our prior results for the area. The two wells currently on-stream delivered IP10 rates of 1,134 boe (85% light oil) and 1,101 boe (77% light oil), respectively, representing the two strongest oil-equivalent rates since the inception of our primary Cardium program. These two wells demonstrated very similar completions flowback rates to three other new wells in the vicinity that will be brought on stream in April.
Obsidian Energy is actively reviewing our portfolio considering the current commodity price outlook and has shut-in volumes deemed temporarily uneconomic to produce and has lowered our first half 2020 production estimate by 600 boe/d. This reduction is composed almost entirely of heavy oil and associated gas production in the Peace River area. Including these actions, the Company expects average production for the first half of 2020 to be within guidance of 26,500 – 27,100 boe/d. The Company will continue to optimize the production base against the anticipated volatile commodity price environment and is prepared to shut-in additional volumes should we deem it economically prudent. In addition, the Company has identified in excess of $10 million in operating and general and administrative reductions over our original 2020 plan and will continue to seek opportunities to lower costs in all aspects of our business.
We are continuing our participation in the ABC program for 2020. Our focus in the first quarter of 2020 has been in the Sousa and Lennard Creek fields in Northwest Alberta, where working in frozen conditions allowed our work to be conducted most efficiently. We have abandoned 149 wells and 138 km of pipelines year to date.
First Half 2020 Production and Cost Guidance
Metric | Guidance Range | |
Production (boe/d) 1 2 3 | 26,500 – 27,100 | |
Capital Expenditures ($millions) | 46 | |
Decommissioning Expenditures ($millions) | 8 | |
Operating Costs ($/boe) | 11.90 – 12.30 | |
General & Administrative ($/boe) | 1.70- 1.90 |
(1) | Adjusted for January 2020 Carrot Creek Disposition of 115 boe/d (85% light oil) | |
(2) | Adjusted for production shut-ins of 600 boe/d due to current oil pricing. | |
(3) | Mid-point of guidance 12,700 bbls/d light oil, 3,200 bbls/d heavy oil, 2,200 bbls/d NGLs and 52,000 mcf/d natural gas |
2020 HEDGING PROGRAM
In 2020, the Company has the following hedges in place:
January | February | March | April | May | June | ||||||
WTI (C$/bbl) | 76.61 | 78.98 | 78.58 | 78.11 | 77.92 | 77.41 | |||||
Total (bbl/day) | 8,250 | 7,750 | 7,000 | 4,000 | 3,000 | 2,000 | |||||
January | February | March | Q2 | Q3 | Q4 | ||||||
(C$/GJ) | 2.40 | 2.33 | - | 1.59 | 1.60 | - | |||||
Total (GJ/day) | 23,000 | 18,000 | - | 25,000 | 24,000 | - |
NYSE LISTING AND OTC LISTING
The significant change in the macro economic environment has contributed to a reduction in the Company's share price. As a result, we no longer meet the listing requirements of the NYSE and will be delisted April 1, 2020. To facilitate trading for our US based shareholders, we will begin trading on the OTCQB effective April 2, 2020. If our share price improves to average over US$0.25 per share for 30 consecutive days, we will move to the OTCQX market. The move in listing from the NYSE to the OTCQB is expected to result in on-going cost savings of approximately $1 million per year at this time.
UPDATED CORPORATE PRESENTATION
For further information on these and other matters, Obsidian Energy has posted an updated Corporate Presentation which can be found on its website, www.obsidianenergy.com.
ADDITIONAL READER ADVISORIES
OIL AND GAS INFORMATION ADVISORY
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
NON-GAAP MEASURES
Certain financial measures including FFO, FFO per share-basic, FFO per share-diluted, netback, net debt and Adjusted EBITDA, included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. FFO is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures, office lease settlements, the effects of financing related transactions from foreign exchange contracts and debt repayments and certain other expenses and is representative of cash related to continuing operations. FFO is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of FFO to cash flow from operating activities, being its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation expenses and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. Net debt is the total of long-term debt and working capital deficiency and is used by the Company to assess its liquidity. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
CALCULATION OF FUNDS FLOW FROM OPERATIONS
Three months ended | Year ended | |||||
($millions, except per share amounts) | 2019 | 2018 | 2019 | 2018 | ||
Cash flow from operating activities | 49 | 19 | 77 | 99 | ||
Change in non-cash working capital | (6) | (22) | 40 | (68) | ||
Decommissioning expenditures | 6 | 4 | 14 | 9 | ||
Onerous office lease settlements | - | 3 | 2 | 13 | ||
Settlements of normal course foreign exchange contracts | - | 2 | - | 3 | ||
Realized foreign exchange loss – debt maturities | - | - | 3 | 8 | ||
Realized foreign exchange loss – hedging repayment 1 | - | - | - | 18 | ||
Restructuring charges 2 | 1 | - | 4 | 8 | ||
Other expenses 3 | 4 | 6 | 20 | 16 | ||
Monetization of transportation contract 4 | (14) | (14) | ||||
Funds flow from operations | 54 | (2) | 160 | 92 | ||
Per share – funds flow from operations | ||||||
Basic per share | 0.74 | (0.03) | 2.20 | 1.26 | ||
Diluted per share | 0.74 | (0.03) | 2.20 | 1.26 |
(1) | In 2018, the Company's outstanding GBP cross currency swap matured resulting in an $18 million realized loss. |
(2) | Excludes the non-cash portion of restructuring. |
(3) | Includes legal fees related to ongoing claims against former Penn West Petroleum Ltd. employees related to the Company's 2014 restatement of certain financial results. In 2017, the Company settled the outstanding lawsuit it had with the United States Securities and Exchange Commission for US$8.5 million (CAD$11 million) during the fourth quarter. |
(4) | In 2018, the Company monetized a physical delivery contract on 15 mmcf of natural gas per day to Northern Border Ventura for US$10.5 million (CAD$14 million). |
ABBREVIATIONS
Oil | Natural Gas | |||
Bbl | barrel or barrels | GJ | Gigajoule | |
bbl/day | barrels per day | GJ/day | gigajoule per day | |
boe/d | barrels of oil equivalent per day | mmcf | million cubic feet | |
Financial | ||||
C$ | Canadian dollars |
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the audited consolidated financial statements and MD&A will be filed in due course on SEDAR and EDGAR; that there are several significant improvements to the underlying business which will result in positive go-forward benefit to cash flow and what those improvements are; that we have flexibility in our portfolio to manage remaining capital expenditures through the balance of 2020 with a view to preserving liquidity and long-term shareholder value; that if the current oil price environment continues, that we anticipate no development capital spending for the balance of 2020; our forecasted H1 spending and the breakdown of that spending, where and when rigs get released, and when completions and decommissioning activities are completed; when certain production will be online and possible caveats to those dates; that the Company will continue to optimize the production base against an anticipated volatile commodity price environment during 2020 and is prepared to shut-in additional volumes should it deem it to be economically prudent; that we will continue to seek opportunities to lower costs in all aspects of our business; that we will continue our participation in the ABC program in 2020; the details of our first half 2020 capital budget and our average production guidance (with breakdown of constituent parts); when we will begin trading on the OTCQB, and that we will move to the OTCQX when we meet the listing criteria; and the expected cost saving from moving from the NYSE to the OTCQB.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that: we will have the ability to continue as a going concern going forward and realize our assets and discharge our liabilities in the normal course of business; we do not dispose of any material producing properties; the impact of the Albert Government curtailment; the impact of any government assistance programs will have on the Company in connection with, among other things, the COVID-19 pandemic; the impact on energy demands going forward and the inability of certain entities, including OPEC, to agree on crude oil production output constraints; the impact on commodity prices, production and cash flow due to the potential lack of storage forcing production shut-ins; how the Supreme Court of Canada Redwater decision will impact our Company moving forward; the impact of regional and/or global health related events on energy demand; global energy policies going forward; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we are not able to continue as a going concern and realize our assets and discharge our liabilities in the normal course of business; the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favorable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, March 29, 2020 /PRNewswire/ -OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce completion of agreements with our lenders and building landlord. All figures are in Canadian dollars unless otherwise stated.
Further to our recent announcements, the Company has executed final agreements resulting in the renewal of our syndicated credit facility, amendments to our senior notes and renewed terms on our Calgary office lease. All terms are consistent as previously announced except for further financial covenant relief, which will provide the Company additional flexibility in the current oil price environment. A summary of the terms is provided below:
NON-GAAP MEASURES
The financial measure Adjusted EBITDA included in this press release does not have a standardized meaning prescribed by IFRS and therefore is considered a non-GAAP measure; accordingly, it may not be comparable to similar measures provided by other issuers. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our updated syndicated credit facility and the possible reconfirmation, redetermination and term-out dates under the various scenarios and elimination of certain financial covenants; our updated senior note maturity dates under various scenarios and elimination of certain financial covenants; and our expected lease payments and indemnity from the landlord going forward.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Albert Government curtailment; the impact of any government assistance programs will have on the Company in connection with, among other things, the COVID-19 pandemic; the impact on energy demands going forward and the inability of certain entities, including OPEC, to agree on crude oil production output constraints; how the Supreme Court of Canada Redwater decision will impact our Company moving forward; the impact of regional and/or global health related events on energy demand; global energy policies going forward; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favorable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Feb. 27, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces the extension of the Company's syndicated credit facility with the underlying borrowing base and amount available under the syndicated credit facility set at $550 million and $450 million, respectively, subject to specific items being amended as discussed below. The amount available under the syndicated credit facility has been reduced by $10 million to the aforementioned $450 million level. Additional terms in the amending agreement are as follows:
The May 31, 2021 revolving period and corresponding November 30, 2021 term periods described above may be accelerated if by March 4, 2020, the following terms are not met:
Failure to satisfy the above terms on or before March 4, 2020 will result in an acceleration of the end date of the revolving period to March 4, 2020 and the end date of the term period to April 1, 2021.
The Company is in active negotiations with our noteholders and building landlord on these outstanding items in order to finalize the extension.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the expected amount available under the syndicated credit facility, the revolving reconfirmation dates and term period; the specific terms which need to be amended including the senior notes and rent payable under the office lease; and expected impact to the credit facility if those terms are not obtained.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; other than noted herein, our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things, the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE.BC"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, Feb. 6, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to release its year-end 2019 independent reserves evaluation.
Stephen Loukas, Interim President and CEO commented, "We are pleased to announce our 2019 reserve results which demonstrates the strength of our dedicated Cardium development strategy, allowing for our reserve auditors to recognize the performance and improved cost efficiency of the program. In addition, the Company received initial recognition of the improvements of existing wells resulting from optimization techniques, thereby resulting in an increase in recoverable reserves."
2019 Year-End Reserves Summary
The Company is pleased to present the results of its year-end 2019 independent reserves evaluation, prepared by Sproule Associates Limited ("Sproule").
2019 marks the Company's third year in a row achieving greater than 100 percent reserve replacement on total proved reserves ("1P") and proved plus probable reserves ("2P"). This increase includes recognition of the performance of our Cardium drilling program contributing to the overall 1P and 2P replacement ratio of approximately 140 and 139 percent, respectively. The Company also continues to see benefits from its optimization and decline mitigation projects with an average projected three year proved developed producing ("PDP") decline of approximately 17 percent. We are excited about the future development opportunities, particularly in our Cardium assets, which will allow us to create long term value for our shareholders.
Reserve Highlights:
2019 Year-End Reserves Tables
In 2019, we engaged Sproule, an independent, qualified engineering firm, to evaluate 100 percent of our PDP, 1P and 2P reserves. Sproule conducted an independent reserves evaluation of Obsidian Energy's reserves effective December 31, 2019. This evaluation was prepared in accordance with definitions, standards, and procedures set out in COGEH and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). The Sproule reserves evaluation was based on Sproule's December 31, 2019 forecast prices and costs. Reserves included below are Company gross reserves which are the Company's total working interest reserves before the deduction of any royalties and excluding any royalty interests payable to the Company. The numbers in the tables below may not add due to rounding.
Summary of Reserves
As at December 31, 2019 | |||||
Reserve | Light & | Heavy | Natural Gas | Conventional | Barrel of Oil |
Estimates Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Proved | |||||
Developed producing | 34 | 5 | 6 | 124 | 65 |
Developed non-producing | 1 | 0 | 0 | 2 | 1 |
Undeveloped | 17 | 1 | 2 | 47 | 28 |
Total Proved | 51 | 6 | 8 | 173 | 94 |
Total Probable | 16 | 3 | 3 | 63 | 32 |
Total Proved plus Probable | 67 | 9 | 11 | 236 | 126 |
Reserves Reconciliation – Proved
Light & | Heavy | Natural Gas | Conventional | Barrel of Oil | |
Reconciliation Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Total Proved | |||||
December 31, 2018 | 47 | 7 | 8 | 176 | 92 |
Extensions | 0 | 0 | 0 | 1 | 0 |
Infill Drilling | 5 | 0 | 1 | 13 | 8 |
Improved Recovery | 0 | 0 | 0 | 0 | 0 |
Technical Revisions | 4 | 0 | 0 | 15 | 7 |
Discoveries | 0 | 0 | 0 | 0 | 0 |
Acquisitions | 0 | 0 | 0 | 0 | 0 |
Dispositions | 0 | 0 | 0 | -7 | -2 |
Economic Factors | 0 | 0 | 0 | -6 | -2 |
Production | -4 | -1 | -1 | -19 | -10 |
December 31, 2019 | 51 | 6 | 8 | 173 | 94 |
Reserves Reconciliation – Proved Plus Probable
Light & | Heavy | Natural Gas | Conventional | Barrel of Oil | |
Reconciliation Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Total Proved Plus Probable | |||||
December 31, 2018 | 64 | 11 | 11 | 233 | 125 |
Extensions | 0 | 0 | 0 | 1 | 1 |
Infill Drilling | 6 | 0 | 1 | 21 | 11 |
Improved Recovery | 0 | 0 | 0 | 0 | 0 |
Technical Revisions | 1 | 0 | 1 | 16 | 4 |
Discoveries | 0 | 0 | 0 | 0 | 0 |
Acquisitions | 0 | 0 | 0 | 0 | 0 |
Dispositions | 0 | 0 | 0 | -9 | -2 |
Economic Factors | 0 | 0 | 0 | -7 | -2 |
Production | -4 | -1 | -1 | -19 | -10 |
December 31, 2019 | 67 | 9 | 11 | 236 | 126 |
Summary of Before Tax Net Present Values
As at December 31, 2019 | |||||
Net Present Value | Discount Rate | ||||
$ millions | Undiscounted | 5 Percent | 10 Percent | 15 Percent | 20 Percent |
Proved | |||||
Developed producing | 523 | 1,217 | 1,010 | 843 | 725 |
Developed non-producing | 35 | 22 | 16 | 13 | 11 |
Undeveloped | 675 | 365 | 210 | 124 | 72 |
Total Proved | 1,232 | 1,605 | 1,236 | 979 | 808 |
Total Probable | 1,209 | 589 | 366 | 259 | 197 |
Total Proved plus Probable | 2,441 | 2,193 | 1,602 | 1,238 | 1,004 |
(1) | The December 31, 2019 reserve net present values include all Obsidian Energy existing well, facility, and pipeline asset retirement obligation estimates, which totals $61 million NPV10. The December 31, 2018 net present value incorporated only existing well abandonment and reclamation costs associated with reserve wells, totaling $24 million NPV10. |
Future Development Capital
As at December 31, 2019 | ||
Future Development Capital | ||
$ millions | Total Proved | Total Proved |
2020 | 83 | 86 |
2021 | 88 | 106 |
2022 | 101 | 120 |
2023 | 123 | 137 |
2024 | 104 | 115 |
2025 and subsequent | ||
Total, Undiscounted | 499 | 564 |
Total, Discounted @ 10% | 390 | 440 |
Summary of Pricing and Inflation Rate Assumptions
Canadian Light | Natural Gas | |||||||
WTI | Sweet Crude | WTI-C | Exchange | |||||
As at December 31, 2019 (1) | Cushing, Oklahoma | 40° API | Spot | Rate | ||||
Sproule Forecast | ($US/bbl) | ($Cdn/bbl) | ($Cdn/MMbtu) | ($US/$Cdn) | ||||
Year | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 | 2019 | 2018 |
Forecast | ||||||||
2020 | 61.00 | 67.00 | 73.84 | 77.89 | 2.04 | 2.44 | 0.76 | 0.80 |
2021 | 65.00 | 70.00 | 78.51 | 82.25 | 2.27 | 3.00 | 0.77 | 0.80 |
2022 | 67.00 | 71.40 | 78.73 | 84.79 | 2.81 | 3.21 | 0.80 | 0.80 |
2023 | 68.34 | 72.83 | 80.30 | 87.39 | 2.89 | 3.30 | 0.80 | 0.80 |
2024 | 69.71 | 74.28 | 81.91 | 89.14 | 2.98 | 3.39 | 0.80 | 0.80 |
2025 | 71.10 | 75.77 | 83.54 | 90.92 | 3.06 | 3.49 | 0.80 | 0.80 |
2026 | 72.52 | 77.29 | 85.21 | 92.74 | 3.15 | 3.58 | 0.80 | 0.80 |
2027 | 73.97 | 78.83 | 86.92 | 94.60 | 3.24 | 3.68 | 0.80 | 0.80 |
2028 | 75.45 | 80.41 | 88.66 | 96.49 | 3.33 | 3.78 | 0.80 | 0.80 |
2029 | 76.96 | 82.02 | 90.43 | 98.42 | 3.42 | 3.88 | 0.80 | 0.80 |
2030 | 78.50 | 92.24 | 3.51 | 0.80 | ||||
(1) Prices Escalate at two percent after 2030, with the exception of foreign exchange which stays flat. |
Updated Corporate Presentation
For further information on these and other matters, Obsidian Energy has posted an updated Corporate Presentation which can be found on its website, www.obsidianenergy.com.
All figures contained in this release are in Canadian dollars unless otherwise noted.
The financial and operating information in this press release is based on estimates and is unaudited. Some of the terms below do not have standardized meanings. Further detail can be found in the "Oil and Gas Advisory" section contained in this release. Additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR, EDGAR, and posted to our website in March.
Oil and Gas Advisory
This press release contains a number of oil and gas metrics, including "F&D costs", and "RLI" which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. F&D costs are the sum of exploration and development costs incurred in the period, plus the change in estimated future development capital for the reserves category, all divided by the change in reserves during the period. F&D costs exclude the impact of acquisitions and divestitures. RLI is calculated as total Company gross reserves divided by Sproule's forecasted 2019 production for the associated reserve category. Under NI 51-101, proved reserves estimates are defined as having a high degree of certainty to be recoverable with a targeted 90 percent probability in aggregate that actual reserves recovered over time will equal or exceed proved reserve estimates. For proved plus probable reserves under NI 51-101, the targeted probability is an equal (50 percent) likelihood that the actual reserves to be recovered will be greater or less than the proved plus probable reserve estimate. The reserve estimates set forth above are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein.
Abbreviations Contained in the Press Release
Oil and Natural Gas Liquids | Natural Gas | ||
bbl | barrel or barrels | mcf | thousand cubic feet |
mmbbl | million barrels | mmcf | million cubic feet |
mmboe | million barrels of oil equivalent | bcf | billion cubic feet |
mcf/d | thousand cubic feet per day | ||
mmcf/d | million cubic feet per day | ||
mmbtu | million British thermal units | ||
mcf | thousand cubic feet | ||
mmcf | million cubic feet | ||
Other | |
AECO | the Alberta benchmark price for natural gas. |
BOE or | barrel of oil equivalent, using the conversion factor of 6 mcf of natural gas being equivalent to one barrel of oil. |
WTI | West Texas Intermediate, the reference price paid in United States dollars at Cushing, Oklahoma for crude oil of standard grade. |
API | American Petroleum Institute. |
°API | the measure of the density or gravity of liquid petroleum products derived from a specific gravity. |
MM$ | million dollars. |
$US | United States dollars |
$C | Canadian dollars |
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we are excited about the future development opportunities, particularly in our Cardium assets, which will allow us to create long term value for our shareholders; that additional reserve information, as required under NI 51-101, will be included in our Annual Information Form which will be filed on SEDAR, EDGAR and our website in March; and our expected RLIs.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Alberta government mandated production curtailment; our ability to execute our long-term plan and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE" and "OBE.BC" respectively. All figures are in Canadian dollars unless otherwise stated.
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-releases-2019-reserves-results-301000045.html
SOURCE Obsidian Energy Ltd.
CALGARY, Jan. 21, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its year-end 2019 production numbers as well as the reconfirmation of its existing credit facility.
Full Year 2019 Production
Full year 2019 production was 26,900 boe/d, within our recent full year guidance range of 26,750 to 27,250 boe/d. Additionally, production in the fourth quarter of 2019 was approximately 26,600 boe/d, with an average December rate of approximately 28,000 boe/d – allowing the Company to enter 2020 with operating momentum.
Reconfirmation of Existing Credit Facility
As previously disclosed, the Company has a reserve-based syndicated credit facility which is subject to a semi-annual borrowing base redetermination typically in May and November of each year. During the third quarter of 2019, the Company reached an agreement (the "Agreement") with its lenders whereby the underlying borrowing base of the syndicated credit facility and the amount available to be drawn under the syndicated credit facility remain at $550 million and $460 million, respectively. Under the Agreement, the Company had, among other things, a reconfirmation date scheduled for January 20, 2020, whereby the commencement of the term-out period may have been accelerated on January 30, 2020. The syndicate lenders have advised they are not terming out the facility and the borrowing base remains unchanged. Also, under the Agreement, a borrowing base redetermination is scheduled for February 28, 2020 when the revolving period is scheduled to end unless extended with the consent of the lenders. If the facility is not extended on or prior to February 28, 2020, the Company would not be allowed to further draw on the syndicated credit facility and the amount outstanding would be due on November 30, 2020.
As at December 31, 2019, the Company had $399 million drawn on the syndicated credit facility compared to $404 million at September 30, 2019.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | |
bbl | barrel or barrels |
bbl/day | barrels per day |
boe/d | barrels of oil equivalent per day |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the next expected redetermination date and the impact to the Company if the lenders do not consent to the extension.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; other than noted herein, our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-provides-year-end-2019-production-and-reconfirmation-of-existing-credit-facility-300990719.html
SOURCE Obsidian Energy Ltd.
CALGARY, Jan. 16, 2020 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to provide an update on our Cardium development program which continues to demonstrate encouraging results as we initiate our 2020 drilling campaign. Additionally, the Company provides the details of recently added hedges to our 2020 program.
Cardium Development Program Update
All 13 wells from the second half of 2019 were successfully brought online prior to the end of December. Results from the program continue to meet the strong production expectations for the area, with IP10 rates for the program averaging 520 boe/d (90% oil) per well (all 13 wells are included in the average), and IP30 rates for wells averaging 485 boe/d (83% oil) per well (11 of the 13 wells are included in the average). We are very encouraged with our capital cost performance, with the wells averaging C$3.5 million per well, down from C$4 million estimated for a comparable well design at our 2018 Investor Day.
Activity is well underway to deliver the nine well program planned for the first half of 2020. Two drilling rigs are active for the Company. Three wells have been rig-released, with the drilling of the fourth and fifth wells underway.
We continue to prepare for our second half 2020 program in the Willesden Green region, which is expected to begin after breakup conditions end.
Hedging Update
The volatility of oil prices over the past several weeks has allowed Obsidian Energy to strengthen its 2020 hedging program, providing additional certainty to our cash flow at levels that are constructive to our business.
Currently, the Company has the following 2020 oil and natural gas hedges in place:
January | February | March | April | May | June | |
WTI C$/bbl | $76.61 | $78.98 | $78.58 | $78.11 | $77.92 | $77.41 |
Total bbl/day | 8,250 | 7,750 | 7,000 | 4,000 | 3,000 | 2,000 |
January | February | |||||
C$/GJ | $2.40 | $2.33 | ||||
Total GJ/day | 23,000 | 18,000 |
Updated Corporate Presentation
For further information on these and other matters, Obsidian Energy has posted an updated Corporate Presentation which can be found on its website, www.obsidianenergy.com.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | GJ | gigajoule |
bbl/day | barrels per day | GJ/day | gigajoule per day |
boe/d | barrels of oil equivalent per day | ||
Financial | |||
C$ | Canadian dollars |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the expected timing for the drilling on the nine well program; the details of our 2020 development program; that we continue to prepare for our second half 2020 program which is expected to begin after breakup conditions end.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; the Alberta mandated production curtailment that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-provides-operational-and-hedging-update-300988735.html
SOURCE Obsidian Energy Ltd.
CALGARY, Dec. 2, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce the appointment of Stephen E. Loukas as Interim President and CEO, effective December 5, 2019. Mr. Loukas will succeed current Interim President and CEO, Michael J. Faust, who will return to his prior position of Independent Director and take on new responsibilities as Chair of the Commercial Committee.
Gordon Ritchie, Chairman of the Board of Directors ("Board"), commented, "I would like to thank Mike for his willingness to step in as Interim President and CEO during such a critical phase in Obsidian Energy's history. His strong leadership and experience was evident as he guided the organization through our new strategy of Cardium only primary development. During the three, very strong, quarters under his stewardship, the Company transformed itself into a much lower cost, highly focused Cardium developer and is well positioned as we enter 2020. As we move into the later stages of our previously announced strategic alternatives process, the Board will continue to leverage our various strengths. Having Stephen step into the Interim President and CEO role at this time will enable the Company to take advantage of his vast experience in corporate transactions and capital markets to guide us through the next period of this process. The reactivated Commercial Committee will ensure that the transition is seamless and that the Company maintains the advantage of Mike's expertise."
Mr. Faust states, "Having achieved the upfront goals of: (i) transforming Obsidian Energy to a Cardium focused development program; (ii) the announcement and implementation of a significant cost savings plan to improve the Company's competiveness, the impact of which will become more visibly evident during 2020; and (iii) the development and approval of the Company's 2020 capital development and operating plan which will continue Obsidian Energy's focus on Cardium primary development; I feel now is an appropriate time to transition out of the Interim President and CEO role. I have worked very closely with Stephen for approaching two years, and I am very confident that he has the right skill set to lead Obsidian Energy through the remainder of the strategic alternative process."
Additional Executive Announcements
Obsidian Energy is pleased to announce the hiring of Mr. Peter Scott as Senior Vice President and Chief Financial Officer, effective December 2, 2019, replacing David Hendry. Mr. Scott has over 30 years of business and financial experience including more than 20 years as Chief Financial Officer of public and private companies. Mr. Scott has been responsible for a wide variety of functional areas including finance, accounting, tax, budgeting and planning, investor relations, insurance, legal, marketing and general administration. Mr. Scott has been intimately involved in a wide variety of business transactions including debt and equity financings, corporate and property acquisitions and dispositions and initial public offerings. Peter's most recent public company role was Senior Vice President and Chief Financial Officer of Lightstream Resources Ltd.
Additionally, Obsidian Energy would like to announce the hiring of Mr. Gary Sykes in the position of Vice President, Commercial, replacing Andrew Sweerts, Mr. Sykes has worked in a variety of technical, operational and managerial positions in locations including the UK, Canada, Indonesia, the USA and the Middle East. From 2012 to 2016 Mr. Sykes was President, Qatar and Iraq for ConocoPhillips managing the company's portfolio of regional assets, and since 2017 has been engaged in supporting a small Private Equity backed oil and gas venture. Mr. Sykes earned an Honors Degree in Mechanical Engineering from Glasgow University in 1990 and a Masters Degree in Petroleum Engineering from Heriot Watt University in Edinburgh in 1991.
Mr. Mark Hawkins has been promoted to Vice President Legal, General Counsel and Corporate Secretary. Mr. Hawkins has served as the corporate secretary since 2015 and was formerly the General Counsel and Corporate Secretary. Prior to joining the Company in March 2015, he was a senior associate with Fasken Martineau DuMoulin LLP in Vancouver from October 2010 to February 2015. Prior thereto, Mr. Hawkins was an associate with McCarthy Tetrault LLP in Calgary from June 2005 to October 2010. Mr. Hawkins has experience in corporate governance, securities and mergers and acquisitions law and has represented clients in a number of significant acquisitions and public offerings.
Reconfirmation of Existing Credit Facility
As previously disclosed, the Company has a reserve-based syndicated credit facility which is subject to a semi-annual borrowing base redetermination typically in May and November of each year. During the third quarter of 2019, the Company reached an agreement with its lenders whereby the underlying borrowing base of the syndicated credit facility and the amount available to be drawn under the syndicated credit facility remain at $550 million and $460 million, respectively. Under the agreement, an additional borrowing base redetermination is scheduled on February 28, 2020 when the revolving period ends, with the expiration of the term-out date of November 30, 2020.
Additionally, there are two reconfirmation dates on November 19, 2019 and January 20, 2020 whereby the commencement of the term-out period may be accelerated on November 30, 2019 and January 30, 2020, respectively. If the facility is not extended on or prior to February 28, 2020 or reconfirmed at the before mentioned dates, the Company would not be allowed to further draw on the syndicated credit facility and the amount outstanding would be due on November 30, 2020.
The Company advises that its borrowing base remained unchanged on November 19, 2019. As a result, the Company's borrowing base and syndicated credit facility remain at $550 million and $460 million, respectively.
Update on Phase 2 Cardium Development
Obsidian Energy has completed drilling the 13 wells planned for 2019, with approval for nine wells in the first half of 2020, completing the Phase 2 program in the Willesden Green area. The Phase 2 program commenced in July 2019 and will be completed in March 2020. This campaign follows a very successful 19 well Phase 1 program, that was conducted from July 2018 to March 2019. Of the 13 wells drilled to date, 11 have been completed, and 7 are on production. Results have been strong, with improved drilling and completion efficiencies resulting in lower costs per well. Average costs for wells to date have been reduced to approximately $3.5 million per well from $3.8 million during the Phase 1 program.
Early production results are also very promising as production for the first 30 days has averaged 438 boed (73% oil) from the 7-24 two (2) well pad; and 575 boe/d (76% oil) from the Northern most 14-24 two (2) well pad. The 12-6 three (3) well pad came on production in mid-November. Initial rates over the first eight (8) days are very strong, averaging 630 boe/d (>90% oil). In addition, early flow back results (2-3 days) from the 2-18 two (2) well pad, and 3-29 two (2) well pad are consistent with recent results in the area, averaging 720 boe/d (90% oil) from the four wells. All 13 wells are expected to be on production before year end.
Approval First Half 2020 Capital Plan
The Board has approved a $49.4 million first half 2020 capital plan to fund the continued drilling of the remaining 9 wells in the Phase 2 program and other operational spending. All wells are expected to be completed prior to breakup.
Hedging Update
Recent volatility within oil and gas markets have allowed the Company to introduce some additional hedges for December 2019 and the first quarter 2020. Our hedge policy is designed to provide a level of certainty to our cash flow at levels that are constructive to our business.
Currently, the Company has the following oil and natural gas hedges in place:
December 2019 | January 2020 | |
WTI $CAD | $C79.25 | $76.40 |
Total bbl/day | 3,950 | 5,000 |
January 2020 | February 2020 | |
C$/GJ | $2.40 | $2.33 |
Total GJ/day | 23,000 | 18,000 |
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | GJ | gigajoule |
bbl/day | barrels per day | GJ/day | gigajoule per day |
boe/d | barrels of oil equivalent per day |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the Board will continue to leverage our various strengths as we move into the later stages of our previously announced strategic alternatives process; that having Mr. Loukas step into the role of Interim President and CEO will enable the Company to take advantage of his vast experience in corporate transactions and capital markets to guide us through the next period of this process; that the reactivation of the Commercial Committee will ensure that the transition is seamless and that the Company maintains the advantage of Mike's operational expertise; the impacts of the costs savings to the Company competitiveness; how the Company will continue its Cardium primary development and expected drilling and completion timing and on production dates for Phase II of the program; and the capital program for the first half of 2020 and on production dates for those wells.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, Nov. 4, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the three and nine months ended September 30, 2019. All figures are in Canadian dollars unless otherwise stated.
Michael Faust, Interim President and CEO, commented, "Throughout the third quarter of 2019, Obsidian Energy continued to deliver on our commitments. We continue to operate within our Funds Flow from Operations, production remains strong and within guidance and we continue to be very pleased by the results we are seeing from the Cardium development program. In addition, we continue to focus on cost reduction efficiencies in our business and the success of these programs are significant, such that we are able to lower our full year operating cost per barrel guidance range to $13.50 - $13.75 per boe."
Financial and Operating Highlights
Three Months ended September 30 | Nine Months ended September 30 | |||||||||
2019 | 2018 | % change | 2019 | 2018 | % change | |||||
Financial (millions, except per share amounts) (4) | ||||||||||
Cash Flow from Operations | $ | 32 | $ | 43 | (26) | $ | 28 | $ | 80 | (65) |
Basic per share | 0.44 | 0.59 | (25) | 0.38 | 1.11 | (66) | ||||
Diluted per share | 0.44 | 0.59 | (25) | 0.38 | 1.11 | (66) | ||||
Funds Flow from Operations (1) | 29 | 26 | 12 | 106 | 93 | 14 | ||||
Basic per share (1) | 0.40 | 0.36 | 11 | 1.46 | 1.29 | 13 | ||||
Diluted per share (1) | 0.40 | 0.36 | 11 | 1.46 | 1.29 | 13 | ||||
Net Income (loss) | (28) | (31) | (10) | (244) | (192) | 27 | ||||
Basic per share | (0.38) | (0.43) | (12) | (3.35) | (2.66) | 26 | ||||
Diluted per share | (0.38) | (0.43) | (12) | (3.35) | (2.66) | 26 | ||||
Capital Expenditures | 27 | 41 | (34) | 69 | 127 | (46) | ||||
Net Debt (1) | $ | 497 | 446 | 11 | 497 | 446 | 11 | |||
Operations | ||||||||||
Daily Production | ||||||||||
Light oil and NGL (bbls/d) | 12,994 | 13,012 | - | 14,043 | 13,473 | 4 | ||||
Heavy oil (bbls/d) | 3,991 | 4,833 | (17) | 4,048 | 5,042 | (20) | ||||
Natural gas (mmcf/d) | 51 | 60 | (15) | 53 | 61 | (13) | ||||
Total production (boe/d) (2) | 25,505 | 27,777 | (8) | 26,989 | 28,633 | (6) | ||||
Average Sales Price | ||||||||||
Light oil and NGL (per bbl) | $ | 59.31 | $ | 75.49 | (21) | $ | 60.53 | $ | 71.27 | (15) |
Heavy oil (per bbl) | 40.44 | 45.30 | (11) | 37.89 | 40.11 | (6) | ||||
Natural gas (per mcf) | $ | 1.05 | $ | 1.87 | (44) | $ | 1.55 | $ | 2.12 | (27) |
Netback per boe (2) | ||||||||||
Sales price | $ | 38.64 | $ | 47.26 | (18) | $ | 40.24 | $ | 45.09 | (11) |
Risk management gain (loss) | 0.60 | (9.28) | >(100) | (1.10) | (6.89) | (84) | ||||
Net sales price | 39.24 | 37.98 | 3 | 39.14 | 38.20 | 2 | ||||
Royalties | (3.12) | (4.56) | (32) | (2.89) | (3.80) | (24) | ||||
Operating expenses (3) | (14.65) | (14.53) | 1 | (13.64) | (14.62) | (7) | ||||
Transportation | (2.72) | (3.71) | (27) | (2.83) | (3.37) | (16) | ||||
Netback (1) | $ | 18.75 | $ | 15.18 | 24 | $ | 19.78 | $ | 16.41 | 21 |
1) | The terms Funds Flow from Operations ("FFO") and their applicable per share amounts, "Net Debt", and "Netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
2) | Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
3) | Includes the benefit of processing fees totaling $2 million for the three months ended September 30, 2019 (2018 – $3 million) and $6 million for the nine months ended September 30, 2019 (2018 - $9 million). |
4) | Effective June 5, 2019, the Company consolidated its common shares on the basis of seven old common shares outstanding |
The table below outlines select metrics in our key development and legacy areas for the three months ended September 30, 2019 and excludes the impact of hedging:
Area | Select Metrics – Three Months Ended September 30, 2019 | |||
Production | Liquids | Operating | Field | |
Cardium | 18,272 boe/d | 66% | $14/boe | $21/boe |
Deep Basin | 1,154 boe/d | 27% | $4/boe | $2/boe |
Alberta Viking | 1,051 boe/d | 39% | $7/boe | $19/boe |
Peace River | 4,519 boe/d | 85% | $13/boe | $15/boe |
Key Development Areas | 24,996 boe/d | 67% | $13/boe | $19/boe |
Legacy Areas | 509 boe/d | 63% | $82/boe | $(14)/boe |
Key Development & Legacy Areas | 25,505 boe/d | 67% | $15/boe | $18/boe |
The table below provides a summary of our operated activity in the third quarter.
Number of Wells Q3 2019 | ||||||
Drilled | Completed | On-stream | ||||
Gross | Net | Gross | Net | Gross | Net | |
Cardium | ||||||
Producer | 6 | 5.3 | 4 | 3.3 | 0 | 0.0 |
Total | 6 | 5.3 | 4 | 3.3 | 0 | 0.0 |
Hedging Program
In the third quarter, the Company capitalized on the volatility of commodity prices building on its fourth quarter hedge position by 2,663 barrels per day at an average price of $79.62 per barrel. The Company will look for opportunities to layer on additional hedges going forward as pricing allows.
Currently, the Company has the following crude oil hedges in place:
Q4 2019 | |
WTI $CAD | 79.44 |
Total bbl/day | 4,613 |
The Company has no currency or gas hedges currently in place.
Phase 2 Cardium Delivers Initial Results
Phase 2 of our Cardium light-oil development drilling program kicked-off early in the third quarter, with 13 wells planned for the second half of 2019 which remains on time and on budget. The initial 10-day production rates from the first two-well pad 7-24-43-8W5, which was brought onstream in mid-October, averaged 547 boe/d and 84% oil. The second two-well pad 14-24-43-8W5 was brought on production shortly thereafter and produced with an average 10-day initial production rate of 682 boe/d day and 87% oil. These wells continue to demonstrate strong early productivity and oil-weighting, consistent with results seen in Phase 1 of the Cardium development program.
Completions operations have been running smoothly with continued cost-discipline and schedule delivery. To date, 12 of 13 planned wells for the second half of 2019 have been rig released, seven of the 13 have been completed and all 13 wells are anticipated to be on production by the end of the year. In the third quarter the Company delivered our longest well to date at 5,487 meters of measured depth (02/05-02-043-08W5), set our pacesetter monobore design well at 10 days (00/09-05-043-07W5), and intermediate-casing well at 12.8 days (00/05-02-043-08W5).
2019 Guidance Updates
Obsidian Energy is pleased to provide updated full year 2019 guidance figures to reflect the progress being made on our top priorities to maintain strong and consistent delivery from our Cardium development program and reduce costs across the business. We have narrowed our expected production range to reflect the consistency of our Cardium development program, as well as the impact of our Carrot Creek asset disposition in the first quarter. The successful cost reduction initiatives employed this year have allowed us to significantly lower our guidance on operating costs and tighten the expected range of G&A. Our updated full year 2019 guidance is below;
Metric | Previous 2019 Guidance Range | Updated 2019 Guidance Range |
Production | 26,750 to 27,750 boe/d | 26,750 to 27,250 boe/d |
Capital Expenditures including | $120 million | $120 million |
Production Growth Rate (1) | Flat | Flat |
Operating Costs | $14.00 - $14.50 per boe | $13.50 - $13.75 per boe |
General & Administrative | $2.00 - $2.50 per boe | $2.10 to $2.35 per boe |
(1) | Relative to full year 2018 A&D adjusted production of 26,900 boe/d |
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | Mcf | thousand cubic feet |
bbl/day | barrels per day | mcf/d | thousand cubic feet per day |
boe/d | barrels of oil equivalent per day | mmcf/d | million cubic feet per day |
NGL | natural gas liquids |
Non-GAAP Measures
Certain financial measures including FFO, FFO per share-basic, FFO per share-diluted, Netback, Net Debt and Adjusted EBITDA included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. FFO is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. FFO is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of FFO to its nearest measure prescribed by IFRS. Operating Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's Operating Netbacks. Field Netback is the per unit of production amount of revenue less royalties, operating expenses and transportation. Net Debt includes long-term debt and includes the effects of working capital and all cash held on hand. See "Reconciliation of Net Debt" below for a calculation of the Company's Net Debt. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
Calculation of Funds Flow from Operations
(millions, except per share amounts) | Three months ended | |||
2019 | 2018 | |||
Cash flow from operating activities | $ | 32 | $ | 43 |
Change in non-cash working capital | (13) | (40) | ||
Decommissioning expenditures | 5 | 2 | ||
Onerous office lease settlements | - | 1 | ||
Realized foreign exchange loss – Debt maturities | - | 18 | ||
Other expenses(1) | 5 | 2 | ||
Funds flow from operations(2) | $ | 29 | $ | 26 |
Per share | ||||
Basic per share | $ | 0.40 | $ | 0.36 |
Diluted per share | $ | 0.40 | $ | 0.36 |
(1) | Includes legal fees related to ongoing claims against former Penn West Petroleum Ltd. employees related to |
(2) | For the first nine months of 2019, FFO increased by $6 million as a result of the adoption of IFRS 16 "Leases". No changes were made to the comparative figures |
Reconciliation of Net Debt
As at | ||||
(millions) | September 30, | December 31, | ||
Long term debt | ||||
Current portion of long-term debt | $ | 18 | $ | 17 |
Long term portion of long-term debt | 449 | 402 | ||
Total | 467 | 419 | ||
Working capital deficiency | ||||
Cash | (5) | (2) | ||
Restricted cash | (2) | - | ||
Accounts receivable | (52) | (53) | ||
Other | (17) | (12) | ||
Bank overdraft | - | 2 | ||
Accounts payable and accrued liabilities | 106 | 143 | ||
Total | 30 | 78 | ||
Net debt | $ | 497 | $ | 497 |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our drilling plans, locations and focuses and when certain wells will be brought on-line; when our costs reduction initiatives for G&A will be fully realized; the expected Net Debt amount at 2019 year end; the expected syndicate credit facility milestone dates; when the Company will provide an update on the strategic alternatives process; that the Company continues to actively pursue the dispositions of its interests in PROP as it focuses its asset base and operations on the Cardium; that the Company will look for opportunities to layer on additional hedges going forward as pricing allows; and the updated guidance for production, operating costs, G&A and production growth.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein (provided that the forward-looking guidance set out herein, does not take into account the potential sale of our interest in Peace River Oil Partnership); the impact of the Alberta mandated production curtailment; the structure and timing of any transaction or strategic alternative and whether any transaction or strategic alternative will be completed; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Oct. 21, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces the reporting date of its upcoming third quarter 2019 financial and operating results and the resignation of its Chief Financial Officer.
Date of Third Quarter Results
Obsidian Energy expects to release its third quarter 2019 financial and operational results before North American markets open on Monday, November 4, 2019. In addition, the third quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on or about the same date.
David Hendry, CFO Resigns
David Hendry, Chief Financial Officer ("CFO") has submitted his resignation, effective November 15, 2019 to pursue another opportunity. Obsidian Energy is currently in discussions to secure a successor and expects to announce a replacement in the near future.
Michael Faust, interim President and Chief Executive Officer, stated, "We thank David for his years of dedication and leadership to the Company, particularly in the role of CFO, and wish him every success in his future endeavors."
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the effective date of our CFO's resignation; the expected timing of announcement for the CFO replacement; and our expected release date for our third quarter financial and operational results and other associated documents.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things, when our current CFO will resign and our quarter release date. Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Oct. 1, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") received notification on October 1, 2019, from the New York Stock Exchange (the "NYSE") that the Company is no longer in compliance with one of the NYSE's continued listing standards because the average closing price of Obsidian Energy's common shares was less than US$1.00 per share over a consecutive 30 trading day period. As of September 27, 2019, the average closing price of Obsidian Energy's common shares over the preceding consecutive 30 trading day period was US$0.99 per share. The issuance of the notification is not discretionary and is sent automatically when a listed company's share price falls below the NYSE's minimum price listing standard.
Under the NYSE's rules, Obsidian Energy can avoid delisting if, within six months from the date of the NYSE notification, its common shares have a closing price on the last trading day of any calendar month and a concurrent 30 trading day average closing price of at least US$1.00 per share. If at the expiration of the applicable cure period Obsidian Energy has not regained compliance, the NYSE will commence suspension and delisting procedures.
As announced on September 10, 2019, the Board of Directors has initiated a formal process to explore strategic alternatives intended to evaluate the Company's strategic options and alternatives to maximize shareholder value. Obsidian Energy believes that this process is in the best interest of shareholders and may result in an increase of the share price over time and thereby bringing Obsidian Energy into compliance with the Minimum Share Price Listing Standard.
Obsidian Energy will continue trading on the NYSE until the end of the compliance cure period, which is expected to be approximately April 1, 2020. If at that time, the Company regains compliance through an increase in its share price, then Company's shares will remain listed on the NYSE. If the Company's share price does not increase sufficiently to meet the continued standards requirements, the Company will not take further steps to regain compliance and expects the NYSE will commence with de-listing procedures
Non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the U.S. Securities and Exchange Commission (the "SEC"), nor does it affect the continued listing and trading of Obsidian Energy's common shares on the Toronto Stock Exchange (the "TSX"). Obsidian Energy intends to notify the NYSE within 10 business days from the date of the notification that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period.
Obsidian Energy's common shares will continue to be listed and traded on the NYSE during the applicable cure period, subject to compliance with the NYSE's other continued listing standards, under the symbol "OBE", but the NYSE will assign a ".BC" indicator to the symbol to denote that Obsidian Energy is below the NYSE's price listing standard. This indicator will be removed at such time as Obsidian Energy is deemed compliant with the NYSE's price listing standard.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, has initiated a formal process to explore strategic alternatives intended to evaluate the Company's strategic options and alternatives to maximize shareholder value; Obsidian Energy believes that this process is in the best interest of shareholders and may result in an increase of the share price over time and thereby bring Obsidian Energy into compliance with the Minimum Share Price Listing Standard; that non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the SEC; Obsidian Energy's ability to regain compliance with the NYSE's price listing standard within the applicable cure period; that if at the expiration of the applicable cure period Obsidian Energy has not regained compliance, the NYSE will commence suspension and delisting procedures; Obsidian Energy's intention to notify the NYSE within 10 business days that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period; and the continued listing and trading of Obsidian Energy's common shares on the TSX and trading on the NYSE until the end of the compliance cure period, at a minimum; if the Company's share price does regained pricing compliance by the end of the period, that it will not take further steps to regain compliance and expects the NYSE will commence with de-listing procedures.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things, our ability to initiate a formal process to explore strategic alternatives to potentially find a transaction on acceptable terms. Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we are unable to identify an acceptable strategic alternative process and/or that we are unable to enter into an agreement in connection with that process on acceptable terms or at all and/or that we are unable to satisfy the conditions precedent set out in any such agreement and are therefore unable to close thereunder, and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Sept. 30, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to provide an update on its Cardium development program and hedging portfolio.
Phase 2 Cardium Program Update
The 13 well Willesden Green Cardium development program planned for the second half of the year is progressing as planned, with six wells rig released. Four of those wells have been completed and are expected to be on stream by mid-October. The Company has seven additional wells planned in the fourth quarter of 2019. All locations are expected to be onstream before the end of the year. The Company is on target to deliver its $120 million capital program, with $75 million of the total spending planned for the second half of the year.
Hedging Program Updates
Recent oil price volatility allowed the Company to build on its fourth quarter hedge position, adding 2,663 barrels per day with an average strike price of $79.62 per barrel, on a Canadian dollar basis. Our hedging policy is designed to provide a level of certainty to our cash flow. While our hedging volumes have increased, we are cautious to only hedge at levels that are constructive to the business.
Currently, the Company has the following crude oil hedges in place:
Q3 2019 | Q4 2019 | |
WTI $CAD | 80.31 | 79.44 |
Total barrels/day | 2,650 | 4,613 |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the 13 well Willesden Green Cardium development program planned for the second half of the year is progressing well; all four wells are expected to be on stream by mid-October; the Company has seven additional wells planned in the fourth quarter of 2019; all locations are expected to be onstream before the end of the year; the Company is on target to deliver its $120 million capital program with $75 million of spending planned for the second half of the year; and what our hedging policy is designed to provide and that we will be cautious to only hedge at levels that are constructive to the business.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Alberta Government mandated curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement
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SOURCE Obsidian Energy Ltd.
CALGARY, Sept. 10, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces that the Board of Directors (the "Board") has determined that it is in the best interest of the Company and its stakeholders to initiate a formal process to explore strategic alternatives.
This process is intended to evaluate the Company's strategic options and alternatives to maximize shareholder value. Such strategic alternatives may include, but are not limited to, a corporate sale, merger or other business combination, a disposition of all or a portion of the Company's assets, a recapitalization, refinancing of its capital structure, or any combination of the foregoing.
While the outcome of the strategic review process will depend on the opportunities which arise within such process (and there is no assurance of any particular outcome), Obsidian Energy believes that, given the Company's position as the largest producer and holder of Cardium acreage, the initiation of the strategic review process will allow for consideration of consolidation within the Cardium play in Alberta. Furthermore, such consolidation if possible, may allow for the creation of additional scale, efficiency and financial strength.
The Board will undertake a broad review of the potential alternatives to enhance stakeholder value and has hired Tudor, Pickering, Holt & Co. as its financial advisor in connection with this review and analysis of strategic alternatives. Given the nature of the strategic alternatives process, the Company does not intend to provide updates until such time as the Board approves a definitive transaction or strategic alternative, or otherwise determines that further disclosure is necessary or appropriate.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the intentions of the strategic alternative process and the possible alternatives that may arise due to such process; that the initiation of the strategic review process will allow for consideration of consolidation within the Cardium play in Alberta and that may allow for the creation of additional scale, efficiency and financial strength; that the Board will undertake a broad review of the potential alternatives to enhance shareholder value; and when the Company will provide updates to the process.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things, our ability to initiate a formal process to explore strategic alternatives to potentially find a transaction on acceptable terms. Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we are unable to identify an acceptable strategic alternative process and/or that we are unable to enter into an agreement in connection with that process on acceptable terms or at all and/or that we are unable to satisfy the conditions precedent set out in any such agreement and are therefore unable to close thereunder, and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 28, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces that the purchase and sale agreement providing for the sale of our 55 percent interest in the Peace River Oil Partnership (the "Partnership") to a third party has been terminated.
In order for the sale to proceed, the consent to the transfer of our Partnership units and the transfer of operatorship of the Partnership was required, however, the consents for these transfers were not obtained and the agreement was terminated.
We intend to pursue all other viable alternatives for the disposition of our interest in the Partnership and continue to focus on our high-quality, light oil Cardium asset.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). In particular, this document contains forward-looking statements pertaining to, without limitation, our intention to pursue all other viable alternatives for the disposition of our interest in the Partnership and continue to focus on our high-quality, light oil Cardium asset. With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things, our ability to successfully dispose of our interest in the Partnership on acceptable terms. Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we are unable to identify another purchaser for our interest in the Partnership and/or that we are unable to enter into an agreement to sell our interest in the Partnership on acceptable terms or at all and/or that we are unable to satisfy the conditions precedent set out in any such agreement and are therefore unable to close thereunder, and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive. The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 14, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the three and six months ended June 30, 2019. All figures are in Canadian dollars unless otherwise stated.
Michael Faust, Interim President and CEO commented "Throughout the second quarter of 2019 we made significant progress on our top priorities: improving our balance sheet, maintaining strong operational results, and making headway on cost cutting initiatives.
In the quarter, we successfully improved the balance sheet by reducing our Net Debt and since quarter end, reached an amended agreement on our syndicated credit facility to maintain our underlying borrowing base and amount available at $550 million and $460 million, respectively.
We continued the momentum from our first quarter with strong operational and financial results. These positive results are due to the Cardium Phase 1 program which continues to perform as expected. Through this dedicated program we have achieved 10 percent production growth in the Cardium versus the second quarter of 2018 and increased our netbacks to $30 per boe in the area. We have now commenced Phase 2 of our Cardium program with two rigs drilling in Willesden Green, and are expecting to see similar results as the Phase 1 program.
In the second quarter, we made progress on our cost cutting initiatives by meaningfully reducing staff in our corporate office to better align with that of a single-asset focused Company. We have also taken steps to reduce our restructuring and other expenses. These efforts ensure we are making the most of every dollar we spend as well as achieving our operating and general and administrative cost targets set for 2020 of $13.00 and $1.85 per boe, respectively."
Second Quarter Financial and Operational Overview
Obsidian Energy maintained strong operational and financial results in the second quarter and continued to focus on its high-quality, light oil Cardium asset. In the quarter, the Company averaged 27,835 boe per day (67 percent oil and NGL's), an increase of 184 boe per day from the first quarter of 2019, despite no new development drilling taking place due to spring break-up. The strong production is attributed to the five Cardium wells that were brought on early in the quarter, as well as an accelerated optimization program that exceeded expectations. Production from the Cardium remained robust at 20,289 boe per day, a five percent increase over the first quarter of 2019 and a 10 percent increase versus the second quarter of 2018. These wells are offsetting the Phase 2 locations that the Company is currently drilling.
Operating Netbacks improved in the second quarter of 2019 to $21.54 per boe, compared to $16.51 per boe in the second quarter of 2018. The increase was largely driven by improved crude oil benchmark pricing and lower operating costs underpinned by the Company's Cardium assets with its Field Netback of $30.35 per boe. As part of our strategic priorities, Obsidian Energy continues to make progress on reducing operating costs which came in at $12.86 per boe for the second quarter of 2019, a decrease of $0.63 per boe versus the previous quarter and $1.61 per boe year over year. The improvements are a result of shutting in legacy asset production in late 2018 and the Company's focus on growing its low operating cost Cardium production.
Funds Flow from Operations ("FFO") in the quarter was $41 million or $0.56 per share, an increase of $5 million from the first quarter of 2019. FFO increased $9 million or 28 percent year over year, due to improved operating costs and lower risk management losses. As expected, Obsidian Energy invested capital, including decommissioning expenditures, totaling $9 million for the second quarter and $45 million in the first half of 2019. With strong FFO and lower capital spending, the Company successfully reduced its Net Debt in the quarter by $19 million, improving the balance sheet.
Financial and Operating Highlights
Three months ended June 30 | Six months ended June 30 | ||||||||||
2019 | 2018 | % change | 2019 | 2018 | % change | ||||||
Financial (millions, except per share amounts)(4) | |||||||||||
Cash Flow from Operations | $ | (3) | $ | (20) | (85) | $ | (4) | $ | 37 | >(100) | |
Basic per share | (0.04) | (0.28) | (86) | (0.05) | 0.51 | >(100) | |||||
Diluted per share | (0.04) | (0.28) | (86) | (0.05) | 0.51 | >(100) | |||||
Funds Flow from Operations (1) | 41 | 32 | 28 | 77 | 67 | 15 | |||||
Basic per share (1) | 0.56 | 0.44 | 27 | 1.06 | 0.93 | 14 | |||||
Diluted per share (1) | 0.56 | 0.44 | 27 | 1.06 | 0.93 | 14 | |||||
Net income (loss) | (162) | (96) | 69 | (216) | (161) | 34 | |||||
Basic per share | (2.22) | (1.33) | 67 | (2.97) | (2.23) | 33 | |||||
Diluted per share | (2.22) | (1.33) | 67 | (2.97) | (2.23) | 33 | |||||
Capital expenditures | 8 | 26 | (69) | 42 | 86 | (51) | |||||
Net Debt (1) | $ | 478 | $ | 408 | 17 | $ | 478 | $ | 408 | 17 | |
Operations | |||||||||||
Daily production | |||||||||||
Light oil and NGL (bbls/d) | 14,654 | 13,379 | 10 | 14,577 | 13,892 | 5 | |||||
Heavy oil (bbls/d) | 4,059 | 5,172 | (22) | 4,077 | 4,963 | (18) | |||||
Natural gas (mmcf/d) | 55 | 61 | (10) | 55 | 61 | (10) | |||||
Total production (boe/d) (2) | 27,835 | 28,697 | (3) | 27,744 | 29,068 | (5) | |||||
Average sales price | |||||||||||
Light oil and NGL (per bbl) | $ | 63.60 | $ | 72.32 | (12) | $ | 61.09 | $ | 68.16 | (10) | |
Heavy oil (per bbl) | 42.63 | 46.81 | (9) | 36.63 | 39.45 | (7) | |||||
Natural gas (per mcf) | $ | 1.18 | $ | 1.62 | (27) | $ | 1.79 | $ | 2.24 | (20) | |
Netback per boe (2) | |||||||||||
Sales price | $ | 42.01 | $ | 45.59 | (8) | $ | 40.99 | $ | 44.04 | (7) | |
Risk management gain (loss) | (1.97) | (7.28) | (73) | (1.89) | (5.73) | (67) | |||||
Net sales price | 40.04 | 38.31 | 5 | 39.10 | 38.31 | 2 | |||||
Royalties | (2.74) | (4.09) | (33) | (2.77) | (3.40) | (19) | |||||
Operating expenses (3) | (12.86) | (14.47) | (11) | (13.17) | (14.66) | (10) | |||||
Transportation | (2.90) | (3.24) | (10) | (2.88) | (3.20) | (10) | |||||
Operating Netback (1) | $ | 21.54 | $ | 16.51 | 30 | $ | 20.28 | $ | 17.05 | 19 |
1) | The terms Funds Flow from Operations and their applicable per share amounts, "Net Debt", and "Netback" are non-GAAP |
2) | Please refer below for the "Oil and Gas Information Advisory" section for information regarding the term "boe", the reconciliation |
3) | Includes the benefit of processing fees totaling $2 million for the three months ended June 30, 2019 (2018 – $3 million) and |
4) | Effective June 5, 2019, the Company consolidated its common shares on the basis of seven old common shares outstanding |
The table below outlines select metrics in our key development and legacy areas for the three months ended June 30, 2019 and excludes the impact of hedging:
Area | Select Metrics – Three Months Ended June 30, 2019 | |||
Production | Liquids | Operating | Field | |
Cardium | 20,289 boe/d | 69% | $11/boe | $30/boe |
Deep Basin | 1,294 boe/d | 17% | $3/boe | $8/boe |
Alberta Viking | 1,041 boe/d | 37% | $13/boe | $17/boe |
Peace River | 4,614 boe/d | 84% | $13/boe | $14/boe |
Key Development Areas | 27,238 boe/d | 68% | $11/boe | $26/boe |
Legacy Areas | 597 boe/d | 53% | $87/boe | $(90)/boe |
Key Development & Legacy Areas | 27,835 boe/d | 67% | $13/boe | $24/boe |
The table below provides a summary of our operated activity in the second quarter.
Number of Wells Q2 2019 | |||||||
Drilled | Completed | On-stream | |||||
Gross | Net | Gross | Net | Gross | Net | ||
Cardium | |||||||
Producer | 0 | 0.0 | 0 | 0.0 | 5 | 5.0 | |
Total | 0 | 0.0 | 0 | 0.0 | 5 | 5.0 |
Hedging Program Updates
The Board of Directors and management have continued to layer additional hedges on a Canadian dollar basis to help minimize volatility in commodity pricing and provide a level of certainty to our cash flow. While our hedging volumes have increased, we are cautious to only hedge at levels that provide investors continued upside. Currently, the Board of Directors have approved up to 5,000 bbl per day of oil hedges extending until the end of the second quarter of 2020.
Currently, the Company has the following crude oil hedges in place:
Q3 2019 | Q4 2019 | |
WTI $CAD | 80.31 | 79.20 |
Total bbl/day | 2,650 | 1,950 |
The Company has no currency or gas hedges currently in place.
Phase 2 Cardium Program Underway
The total planned capital of $120 million for 2019 remains unchanged with a second half 2019 capital spend of $75 million, including decommissioning expenditures. Of the of $75 million, approximately $50 million will be allocated to drill 13 primary Cardium wells. The remaining $25 million of capital will be earmarked for further Cardium wellbore optimization, non-operated development, maintenance and corporate capital. The Company will continue to target spending within FFO and depending on commodity price, has an inventory of drill ready locations to adjust development activity accordingly.
After a wet spring break-up season, the Company began Phase 2 of its Cardium drilling program mobilizing two rigs to the Crimson area. The first of two wells 5-23-43-8W5 was spud July 28 and has been rig released with the second well 102/10-22-43-08W5 spud July 31. Each rig is currently drilling two-well pads with all four wells estimated to be on stream by mid-October. The Company has nine additional wells planned in 2019 with all locations fully licensed and ready to execute. These locations utilize existing infrastructure to minimize costs and are along trend with the previous best in class Cardium results the Company achieved during its Phase 1, 19 well program in late 2018 and early 2019. Obsidian Energy does not expect that the Alberta government mandated curtailment program will impact its operations with the assumption that it will remain in place through the balance of 2019. As part of normal course operations, the Company has planned turnaround activity scheduled in the third quarter of 2019. Consequently, the Company's operating cost per boe metric for the third quarter is likely to increase but expects to remain within its annual guidance range.
Capital Program Details:
Capital Category | # of Wells | Net Capital |
Cardium | 18 Producers | $81 million |
Non-Operated Development | 2.5 net Producers | $6 million |
Existing Wellbore Optimization | >25 Projects | $5 million |
Maintenance & Corporate | $16 million | |
Capital Expenditures | $108 million | |
Decommissioning Expenditures | $12 million | |
Total | $120 million |
There have been no changes to the full year production and cost guidance figures. Guidance will be updated following the close of the Peace River asset disposition. A summary of the key figures is outlined below:
Metric | 2019 Guidance Range |
Production | 26,750 to 27,750 boe per day |
Capital Expenditures including | $120 million |
Production Growth Rate (1) | Flat |
Operating Costs | $14.00 - $14.50 per boe |
General & Administrative | $2.00 - $2.50 per boe |
(1) | Relative to full year 2018 A&D adjusted production of 26,900 boe per day |
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | Mcf | thousand cubic feet |
bbl/day | barrels per day | mcf/d | thousand cubic feet per day |
boe/d | barrels of oil equivalent per day | mmcf/d | million cubic feet per day |
NGL | natural gas liquids |
Non-GAAP Measures
Certain financial measures including FFO, FFO per share-basic, FFO per share-diluted, Netback, Net Debt and Adjusted EBITDA included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. FFO is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. FFO is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of FFO to its nearest measure prescribed by IFRS. Operating Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's Operating Netbacks. Field Netback is the per unit of production amount of revenue less royalties, operating expenses and transportation. Net Debt includes long-term debt and includes the effects of working capital and all cash held on hand. See "Reconciliation of Net Debt" below for a calculation of the Company's Net Debt. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
Calculation of Funds Flow from Operations
(millions, except per share amounts) | Three months ended June 30 | |||
2019 | 2018 | |||
Cash flow from operating activities | $ | (3) | $ | (20) |
Change in non-cash working capital | 32 | 26 | ||
Decommissioning expenditures | 1 | 1 | ||
Onerous office lease settlements | 1 | 4 | ||
Realized foreign exchange loss – Debt maturities | 3 | 8 | ||
Restructuring charges | 2 | 7 | ||
Other expenses(1) | 5 | 6 | ||
Funds flow from operations(2) | $ | 41 | $ | 32 |
Per share | ||||
Basic per share | $ | 0.56 | $ | 0.44 |
Diluted per share | $ | 0.56 | $ | 0.44 |
(1) | Includes legal fees related to ongoing claims against former Penn West Petroleum Ltd. ("Penn West") employees related to | |||||||
(2) | For the first six months of 2019, FFO increased by $4 million as a result of the adoption of IFRS 16 "Leases". No changes were made to the comparative figures |
Reconciliation of Net Debt
As at | ||||
(millions) | June 30, | December 31, | ||
Long term debt | ||||
Current portion of long-term debt | $ | 434 | $ | 17 |
Long term portion of long-term debt | 44 | 402 | ||
Total | 478 | 419 | ||
Working capital deficiency | ||||
Cash | (2) | (2) | ||
Accounts receivable | (63) | (53) | ||
Other | (12) | (12) | ||
Bank overdraft | 1 | 2 | ||
Accounts payable and accrued liabilities | 76 | 143 | ||
Total | 0 | 78 | ||
Net debt | $ | 478 | $ | 497 |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the Company is expecting to see similar results in the Phase 2 program to that of the Phase 1 program in the Cardium; that the Company will make the most of every dollar spent to help achieve our operating and general and administrative cost targets set for 2020; that the reduction in both staff and information technology spending levels will result in lower absolute costs in the second half of the year; the terms of the amended syndicated credit facility, including the revolving period, confirmation and term-out dates and revised amount available after the Peace River Oil Partnership disposition; that hedges entered into will help minimize volatility in commodity pricing and provide a level of certainty to the cash flow; our total planned capital for 2019 and how that will be structured; that the Company will continue to target spending within FFO and depending on commodity price, having drill ready locations to adjust development activity accordingly; our drilling plans, locations and focuses; our expectation for the Alberta government mandated curtailment program impact on the Company; our expected turnaround activity and the impact that will have to the Company operating costs per boe for the quarter; and the guidance for production, operating costs, G&A and production growth and when that will be updated.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein (provided that the forward-looking guidance set out herein, does not take into account the pending sale of our interest in Peace River Oil Partnership other than the proposed borrowing base of the syndicated credit facility); the impact of the Alberta mandated production curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 13, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces the extension of the Company's syndicated credit facility with the underlying borrowing base and amount available under the syndicated credit facility remaining at $550 million and $460 million, respectively. The revolving period ends on February 28, 2020 with revolving period reconfirmation dates on November 19, 2019 and January 20, 2020. Under the agreement, the term-out period is extended to November 30, 2020.
As part of the Peace River Oil Partnership disposition, our partner has waived its right to exercise both the right of first refusal and the tag along provisions. Furthermore, the transaction has received the advanced ruling certificate from the Competition Bureau of Canada. The disposition continues to proceed through the usual steps, including terms of the agreement and customary closing conditions. Obsidian Energy expects to close the transaction by the end of August and will provide updates as they arise. Upon the close of the transaction, the amount available under the syndicated credit facility will be reduced to $420 million.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the expected amount available under the syndicated credit facility, the revolving reconfirmation dates and term-out period; the anticipating closing date for the PROP disposition; and the expected borrowing base and capacity after the PROP disposition.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than noted herein; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; our partners ability to progress through their right of first refusal and tag-along provisions in connection with the Peace River Oil Partnership disposition; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things, the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 6, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces reporting date of its second quarter 2019 financial and operational results.
Obsidian Energy expects to release its second quarter 2019 financial and operational results before North American markets open on Wednesday, August 14, 2019. In addition, the second quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
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SOURCE Obsidian Energy Ltd.
CALGARY, July 23, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") received notification from the New York Stock Exchange (the "NYSE") that we have regained compliance with the NYSE's continued listing standard regarding the price of Obsidian Energy's common shares.
The Company had received notification regarding the price deficiency on September 18, 2018. In an effort to regain compliance, the Company filed articles of amendment on June 5, 2019 to consolidate the common shares of the Company on the basis of a consolidation ratio of seven old common shares to one new common share (the "Common Share Consolidation"). At the Annual and Special meeting the Common Share Consolidation was approved by shareholders and commenced trading on a post consolidation basis on June 10, 2019.
The NYSE continued listing standard requires that the average closing price of a listed company's common stock be no less than US$1.00 per share over a consecutive 30 trading day period and close at or above US$1.00 per share on the last trading day of the cure period to regain compliance. The Company has been notified by the NYSE that it has cured the price condition and regained compliance with all NYSE continued listing requirements as of July 23, 2019 and will continue to trade on the NYSE.
Obsidian Energy shares are listed on the Toronto Stock Exchange and the New York Stock Exchange under the symbol "OBE".
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SOURCE Obsidian Energy Ltd.
CALGARY, July 1, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces the Company's banking syndicate has extended the syndicated credit facility redetermination date until August 30, 2019 as we progress through the necessary provisions in regard to the Peace River Oil Partnership ("PROP") disposition and continue to evaluate the potential of an unsecured bond offering, which remains subject to market conditions and acceptable terms. The borrowing base under the syndicated credit facility continues to be $550 million with capacity of $460 million during the extension period. Obsidian Energy anticipates closing the PROP disposition on or about July 31, 2019.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we will continue to progress through the PROP disposition and evaluate the unsecured bond offering, subject to market conditions and acceptable terms; the expected borrowing base and capacity during the extension period; and the anticipated closing date of the PROP disposition.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; our partners ability to progress through their right of first refusal and tag-along provisions in connection with the Peace River Oil Partnership disposition; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things, the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE.BC"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, June 5, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy" or the "Company") is pleased to announce that at its annual and special meeting of shareholders held on June 5, 2019, Obsidian Energy's shareholders approved all resolutions outlined in the Notice of 2019 Annual and Special Meeting and Management Proxy Circular dated April 15, 2019 (the "Information Circular"), which is available on SEDAR at www.sedar.com, on EDGAR at www.sec.gov, and on Obsidian Energy's website at www.obsidianenergy.com
The Company filed articles of amendment on June 5, 2019 to effect the consolidation of the common shares of the Company on the basis of a consolidation ratio of seven old common shares to one new common share (the "Common Share Consolidation"). No fractional common shares will be issued pursuant to the Common Share Consolidation. In lieu of any such fractional common shares, each registered shareholder of the Company otherwise entitled to a fractional common share following the implementation of the Common Share Consolidation will receive the nearest whole number of post-consolidation common shares.
Letters of transmittal will be mailed to registered shareholders of the Company on June 6, 2019 and such registered holders are required to deposit their share certificate(s), together with the duly completed letter of transmittal, with AST Trust Company (Canada), the Company's registrar and transfer agent. Non-registered shareholders holding common shares through an intermediary (a securities broker, dealer, bank or financial institution) should be aware that the intermediary may have different procedures for processing the Common Share Consolidation than those that will be put in place by the Company for registered shareholders. If shareholders hold their common shares through an intermediary and they have questions in this regard, they are encouraged to contact their intermediaries.
Trading on a post-consolidation basis will commence on both the New York Stock Exchange and Toronto Stock Exchange on or about June 10, 2019.
1. Appointment of Auditor
By resolution passed by show of hands, Ernst & Young LLP, Chartered Accountants, was appointed as auditor of Obsidian Energy for the ensuing year.
2. Election of Directors
By resolutions passed by ballot vote, the following eight nominees proposed by management were elected as directors of the Company to hold office until the next annual meeting of Shareholders or until their successors are elected or appointed:
Name of Nominee | |||||
Votes For | Percent | Votes Withheld | Percent | ||
John Brydson | 164,297,713 | 86.79% | 24,998,999 | 13.21% | |
Raymond D. Crossley | 147,580,742 | 77.96% | 41,715,970 | 22.04% | |
Michael J. Faust | 164,344,034 | 86.82% | 24,952,678 | 13.18% | |
William A. Friley | 147,650,568 | 78.00% | 41,646,144 | 22.00% | |
Maureen Cormier Jackson | 146,847,053 | 77.58% | 42,449,659 | 22.42% | |
Edward H. Kernaghan | 158,840,080 | 83.91% | 30,456,632 | 16.09% | |
Stephen Loukas | 162,598,322 | 85.90% | 26,698,390 | 14.10% | |
Gordon Ritchie | 163,267,417 | 86.25% | 26,029,295 | 13.75% |
3. Non-Binding Advisory Vote on the Corporation's Approach to Executive Compensation
By resolution passed by ballot vote, an advisory resolution was passed to approve the Company's approach to executive compensation as outlined in the Information Circular. The results of the ballot were as follows:
Votes For | Percent | Votes Withheld | Percent |
154,143,435 | 81.43% | 35,152,624 | 18.57% |
4. Approval of Share Consolidation
By resolution passed by ballot vote, a special resolution was passed to authorize and approve the filing of Articles of Amendment to consolidate the issued and outstanding common shares of the Company on the basis of seven old common shares for one new share, as outlined in the Information Circular. The results of the ballot were as follows:
Votes For | Percent | Votes Withheld | Percent |
245,773,172 | 80.43% | 59,802,548 | 19.57% |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the expected date for mailing of letters of transmittal to registered shareholders and the expected date that the common shares will trade on a post-consolidation basis on the Toronto Stock Exchange and New York Stock Exchange. All statements, other than statements of historical facts, that address activities that Obsidian Energy assumes, plans, expects, believes, projects, aims, estimates or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements provided in this news release are based on management's current belief, based on currently available information, as to the outcome and timing of future events. Obsidian Energy cautions that its intention to proceed with the Common Share Consolidation and other forward-looking statements relating to Obsidian Energy are subject to all of the risks and uncertainties normally incident to such endeavors. These risks relating to Obsidian Energy include, but are not limited to, the risk that trading on a post-consolidation basis will not take effect when expected and other risks as described in reports (including, without limitation, under the heading "Risk Factors" in the Company's Annual Information Form for the year ended December 31, 2018) on file with Canadian and US securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com), through the SEC website (www.sec.gov), and at Obsidian Energy's website (www.obsidianenergy.com).
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE.BC"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, June 3, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces the Company's banking syndicate has extended the syndicated credit facility redetermination date until June 30, 2019 as the Company completes marketing of its previously announced unsecured bond offering and as our partner progresses through its right of first refusal and tag-along provisions in regard to the Peace River Oil Partnership disposition. The completion of an unsecured bond offering is subject to market conditions and acceptable terms. Proceeds of the offering would be used to repay existing debt.
The borrowing base under the syndicated credit facility will remain at $550 million with capacity of $460 million during the extension period. Additionally, under the terms of the syndicated credit facility, the Company will be required to have a minimum Liability Management Rating ("LMR") of 1.50 going forward. Currently, the Company's LMR is approximately 1.74.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the use of proceeds from the unsecured bond offering; the expected borrowing base and capacity during the extension period and the minimum requirement of LMR going forward.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; our partners ability to progress through their right of first refusal and tag-along provisions in connection with the Peace River Oil Partnership disposition; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things, the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE.BC"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, May 19, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce the following:
Fixed Income Investor Meetings
Obsidian Energy Ltd. has engaged Pareto Securities ("Pareto") to arrange fixed income investor meetings in conjunction with a potential unsecured bond issuance.
Following these meetings, and subject to market conditions and acceptable terms, a 5-year senior unsecured bond issue of up to US$100 million (the "Bond Issue") may take place. The proceeds from the Bond Issue would be used to refinance Obsidian Energy's existing US$48 million secured notes as at May 31, 2019 maturing between 2020 to 2025 and for general corporate purposes.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the Bond Issue and the use of proceeds from that issuance.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Alberta Government curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things, the factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange (symbol "OBE") and New York Stock Exchange (symbol "OBE.BC"). All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, May 17, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce it has signed a purchase and sale agreement (the "Agreement") to sell its 55% working interest in the Peace River Oil Partnership ("PROP") for total consideration of approximately $97 million, before normal closing adjustments. Total consideration includes $85.8 million in cash and cash equivalents, with the remainder comprised of purchasers' shares and the present value of additional liabilities. The Agreement is subject to financing and the terms of the partnership agreement which provides for a 30-day right of first refusal with an additional 15-day tag-along right to our partner. The effective date of the transaction is February 1, 2019 with an anticipated closing date on or about July 31, 2019. All figures are in Canadian dollars unless otherwise stated.
Strategic Rationale
Consistent with our previously announced strategy, this transaction divests a significant non-core, lower netback asset, reduces our overall corporate operating costs and allows the Company to focus on our Cardium assets. Along with the sale of PROP, the Company will be divesting other non-producing assets in the area, which reduces our total decommissioning liabilities. Proceeds will be used to strengthen our balance sheet by paying down debt, with additional consideration going towards growing our fast-cycle primary oil development program. Transaction metrics are outlined below:
Transaction Metrics | |
Transaction Value | $97 million |
Production (1) | 4,160 boe/d |
Implied Production Multiple | $23,300/boe |
Net Operating Income ("NOI") (2)(3) | $15.0 million |
Implied NOI Multiple | 6.5x |
(1) | Production is based on the estimated next twelve months |
(2) | NOI is based on May 15th strip pricing for the estimated next twelve months |
(3) | The term NOI is a non-GAAP measure. Please refer to the "Non-GAAP Measures Advisory" section below for further details. |
Advisors
Scotiabank acted as financial advisor to Obsidian Energy with respect to this transaction.
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures Advisory
NOI does not have a standardized meaning prescribed by IFRS and therefore is considered a non-GAAP measure; accordingly, it may not be comparable to similar measures provided by other issuers. NOI is the production amount of revenue less royalties, operating expenses, and transportation expenses.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the sale of our working interest in PROP and other non-producing assets in the area and the components of such a sale; the anticipated reduction to our total decommissioning liability; the use of proceeds; that the sale will allow us to focus on our Cardium assets; and the anticipated closing date for the transaction.
The key metrics for the Company set forth in this release may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information contained in this release are based on assumptions about future events based on management's assessment of the relevant information currently available. In particular, this release contains projected operational and financial information for 2019 and beyond for the Company. The future-oriented financial information and financial outlooks contained in this presentation have been approved by management as of the date of this release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein; the impact of the Alberta Government curtailment; our ability to execute our long-term plan and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility of non-completion of the transaction or delayed completion of the transaction due to financing risk by the purchaser; the possibility that approvals are not obtained for the transaction from regulators or partners on a timely basis or at all; the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, May 10, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the three months ended March 31, 2019. All figures are in Canadian dollars unless otherwise stated.
Michael Faust, Interim President and CEO commented "Stepping into my role at Obsidian Energy, I am focusing my attention on three main areas. First, I will ensure we continue to deliver strong and repeatable well results from our Cardium asset, focused on growing our light oil production, consistent with the recent performance of the first 19 well program. Second, I will prioritize the strength of our balance sheet by ensuring we are spending within funds flow from operations and seek to divest non-core properties, if the market conditions are favorable, to reduce our overall leverage profile. My third priority will be to conduct a thorough review of our cost structure to identify areas for improvement, aiming to bring our costs in line with peers. This initiative will be focused on both capital expenditures and expenses. This will include streamlining internal processes, improving operational productivity, and enhancing capital efficiencies. Details of the cost reduction initiatives will be presented at the Annual General Meeting."
Demonstrating Cardium Deliverability
During the first quarter of 2019, the Company drilled, completed and equipped five Cardium wells (5.0 net). Of the 2019 wells that we have drilled to date, we are particularly excited about our 12-18, three well pad, which has averaged initial production rates over the first 30 days ("IP30") of 620 boe per day per well and approximately 83 percent oil. The 12-18 pad is the most northern pad drilled in the Crimson area, further demonstrating the extent of our Willesden Green inventory. Over the past nine months, the Company has drilled 19 Cardium wells (19.0 net) averaging an IP30 of 538 boe per day per well and approximately 86 percent oil.
The next phase of the program will resume after spring break-up and continue until March 2020. We have all our locations ready to license with the construction of the first two pads expected to commence as soon as road conditions and weather permits.
Q1 Production Beat and Improved Liquids Weighting
Obsidian Energy delivered strong operational results in the first quarter 2019, highlighted by average oil production of 16,472 bbl per day and average total production of 27,651 boe per day. Both figures are ahead of our pre-released target ranges for the quarter. The production beat is attributed to the Cardium program's strong production rates and was achieved in spite of considerably colder temperatures observed in February.
The Company's liquids production weighting also improved in the first quarter of 2019 to 67 percent liquids, a three percent increase over the fourth quarter of 2018. This shift was the result of our gas weighted legacy production that was shut-in toward the end of 2018 and early 2019. The Company plans to further rationalize the portfolio to focus the Company towards light oil and higher margin production.
Strong Cash Flow Generation
With continued positive operational momentum and significant improvements in Canadian benchmark prices, first quarter of 2019 funds flow from operations ("FFO") was $36 million or $0.07 per share, a $38 million increase over the previous quarter.
Operating netbacks in the first quarter of 2019 were $18.98 per boe, a $17.00 per boe increase compared to the fourth quarter of 2018. The increase was largely driven by crude oil differential improvements, underpinned by the Company's focus on its light oil, low operating cost Cardium development program which resulted in a realized field netback in the first quarter of 2019 of $28.08 per boe, an increase of $16.87 per boe compared to the previous quarter.
Financial and Operating Highlights
Three months ended March 31 | ||||||
2019 | 2018 | % change | ||||
Financial (millions, except per share amounts) | ||||||
Cash Flow from Operations | $ | (1) | $ | 57 | >(100) | |
Basic per share | - | 0.11 | (100) | |||
Diluted per share | - | 0.11 | (100) | |||
Funds Flow from Operations (1) | $ | 36 | $ | 35 | 3 | |
Basic per share (1) | 0.07 | 0.07 | - | |||
Diluted per share (1) | 0.07 | 0.07 | - | |||
Net loss | (54) | (65) | (17) | |||
Basic per share | (0.11) | (0.13) | (15) | |||
Diluted per share | (0.11) | (0.13) | (15) | |||
Capital expenditures | 34 | 60 | (43) | |||
Net Debt (1) | $ | 497 | $ | 405 | 23 | |
Operations | ||||||
Daily production | ||||||
Light oil and NGL (bbls/d) | 14,498 | 14,412 | 1 | |||
Heavy oil (bbls/d) | 4,096 | 4,751 | (14) | |||
Natural gas (mmcf/d) | 54 | 62 | (13) | |||
Total production (boe/d) (2) | 27,651 | 29,443 | (6) | |||
Average sales price | ||||||
Light oil and NGL (per bbl) | $ | 58.52 | $ | 64.25 | (9) | |
Heavy oil (per bbl) | 30.62 | 31.34 | (2) | |||
Natural gas (per mcf) | $ | 2.41 | $ | 2.87 | (16) | |
Netback per boe (2) | ||||||
Sales price | $ | 39.95 | $ | 42.52 | (6) | |
Risk management gain | (1.80) | (4.20) | (57) | |||
Net sales price | 38.15 | 38.32 | - | |||
Royalties | (2.81) | (2.73) | 3 | |||
Operating expenses (3) | (13.49) | (14.86) | (9) | |||
Transportation | (2.87) | (3.16) | (9) | |||
Netback (1) | $ | 18.98 | $ | 17.57 | 8 |
1) | The terms FFO and their applicable per share amounts, "Net Debt", and "netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
2) | Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe" |
3) | Includes the benefit of processing fees totaling $2 million for 2019 (2018 – $3 million) |
The table below outlines select metrics in our key development and legacy areas for the three months ended March 31, 2019 and excludes the impact of hedging:
Area | Select Metrics – Three Months Ended March 31, 2019 | |||
Production | Liquids | Operating | Netback | |
Cardium | 19,375 boe/d | 70% | $13/boe | $28/boe |
Deep Basin | 1,501 boe/d | 21% | $2/boe | $13/boe |
Alberta Viking | 1,009 boe/d | 40% | $15/boe | $16/boe |
Peace River | 4,449 boe/d | 88% | $14/boe | $8/boe |
Key Development Areas | 26,334 boe/d | 69% | $12/boe | $23/boe |
Legacy Areas | 1,317 boe/d | 36% | $38/boe | $(30)/boe |
Key Development & Legacy Areas | 27,651 boe/d | 67% | $13/boe | $21/boe |
The table below provides a summary of our operated activity in the third quarter.
Number of Wells Q1 2019 | ||||||||
Drilled | Completed | On-stream | ||||||
Gross | Net | Gross | Net | Gross | Net | |||
Cardium | ||||||||
Producer | 5 | 5.0 | 9 | 9.0 | 4 | 4.0 | ||
Peace River | 0 | 0.0 | 0 | 0.0 | 2 | 1.1 | ||
Total | 5 | 5.0 | 9 | 9.0 | 6 | 5.1 | ||
Hedging Program and Strategy Updates
The Board of Directors and management have completed a fulsome review of our hedging strategy and believe that a conservative hedging strategy will help provide certainty to our cash flow and capital programs for 2019 and 2020. This combined with our capital flexibility improves our ability to live within FFO, while offering investors continued upside exposure to improving commodity prices. At current prices, the program economics are robust, and as such, the Company has begun building a hedging position for the second half of 2019 and will work towards building a 2020 position. The Company plans to take hedging contracts on a Canadian dollar basis to limit foreign exchange management and where liquidity exists, hedge Canadian differentials to protect wellhead pricing.
Currently, the Company has the following crude oil hedges in place:
Q2 2019 | Q3 2019 | Q4 2019 | |
WTI $USD | $56.53 | - | - |
bbl/day | 2,000 | - | - |
WTI $CAD | $68.58 | $83.47 | $82.10 |
bbl/day | 4,000 | 950 | 550 |
Total | |||
bbl/day | 6,000 | 950 | 550 |
The Company has no currency or gas hedges currently in place.
Increasing our Cardium Focus in the 2019 Capital Program
The Cardium continues to deliver strong results as evidenced by the recently announced operational results and our quarterly production rates. As part of our disciplined capital allocation review, management has elected to remove $7 million of capital previously earmarked for two Deep Basin wells and reallocate this capital to our Cardium asset adding two additional wells. The Company now plans to drill a total of 18 Cardium wells in 2019, reaffirming its focus on the short cycle, light oil and highest margin asset in our portfolio.
At this time, the total planned capital of $120 million for 2019 remains unchanged, with the Board approving a second half 2019 capital spend, including decommissioning expenditures, of $75 million. Of the approved second half capital spend, approximately $50 million will be allocated to drilling 13 primary Cardium wells. The capital program remains flexible, with the ability to increase development activity should pricing allow.
Updated Capital Program Details:
Capital Category | # of Wells | Net Capital |
Cardium | 18 Producers | $81 million |
Non-Operated Development | 2.5 net Producers | $6 million |
Existing Wellbore Optimization | >25 Projects | $5 million |
Maintenance & Corporate | $16 million | |
Capital Expenditures | $108 million | |
Decommissioning Expenditures | $12 million | |
Total | $120 million |
There are no changes to the full year production and cost guidance figures. A review of the figures is outlined in the table below:
Metric | 2019 Guidance Range |
Production | 26,750 to 27,750 boe per day |
Capital Expenditures including | $120 million |
Production Growth Rate (1) | Flat |
Operating Costs | $14.00 - $14.50 per boe |
General & Administrative | $2.00 - $2.50 per boe |
(1) | Relative to full year 2018 A&D adjusted production of 26,900 boe per day |
Annual and Special Meeting to be held June 5, 2019
The Company's Annual and Special Meeting (the "Meeting") for Shareholders is scheduled on Wednesday, June 5, 2019 at 9:00 a.m. Mountain Time (11:00 a.m. Eastern Time). The Meeting will be held in the SunAlta Ballroom of the Marriott Downtown Hotel, located at 110 – 9th Avenue SE Calgary, Alberta.
There will be a corporate presentation given by Michael Faust, Interim President and CEO during the Meeting.
To listen to a live broadcast of the presentation and the question and answer period, please access the following URL: https://event.on24.com/wcc/r/1990022/E40D0DB297F639B0E3563F924B869040
A replay of the audio webcast and a link to the Meeting presentation will be available two hours afterwards on our website at www.obsidianenergy.com
Electronic copies of our Management Information Circular, Proxy Statement, financial statements, news releases, and other public information are available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | Mcf | thousand cubic feet |
bbl/day | barrels per day | mcf/d | thousand cubic feet per day |
boe/d | barrels of oil equivalent per day | mmcf/d | million cubic feet per day |
Non-GAAP Measures
Certain financial measures including FFO, FFO per share-basic, FFO per share-diluted, Netback, net debt and Adjusted EBITDA included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. FFO is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. FFO is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of FFO to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's Netbacks. Net debt includes long-term debt and includes the effects of working capital and all cash held on hand. See "Reconciliation of Net Debt" below for a calculation of the Company's Net Debt. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
Calculation of Funds Flow from Operations
(millions, except per share amounts) | Three months ended March 31 | |||
2019 | 2018 | |||
Cash flow from operating activities | $ | (1) | $ | 57 |
Change in non-cash working capital | 27 | (32) | ||
Decommissioning expenditures | 2 | 2 | ||
Onerous office lease settlements | 1 | 5 | ||
Restructuring charges – cash portion | 1 | 1 | ||
Other expenses(1) | 6 | 2 | ||
Funds flow from operations | $ | 36 | $ | 35 |
Per share | ||||
Basic per share | $ | 0.07 | $ | 0.07 |
Diluted per share | $ | 0.07 | $ | 0.07 |
(1) | Includes legal fees related to ongoing claims against former Penn West Petroleum Ltd. ("Penn West") employees related to the Company's 2014 restatement of certain financial results |
Reconciliation of Net Debt
As at | |||||
(millions) | March 31, 2019 | March 31, 2018 | |||
Long term debt | |||||
Current portion of long-term debt | $ | 30 | $ | 32 | |
Long term portion of long-term debt | 428 | 335 | |||
Total | 458 | 367 | |||
Working capital deficiency | |||||
Cash | (3) | (2) | |||
Accounts receivable | (70) | (102) | |||
Other | (12) | (14) | |||
Bank overdraft | 1 | - | |||
Accounts payable and accrued liabilities | 123 | 156 | |||
Total | 39 | 38 | |||
Net debt | $ | 497 | $ | 405 | |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we will continue to deliver strong and repeatable well results from our fast track light oil Cardium assets, consistent with the strong performance of the first 19 wells in the program; that we are working to deliver the best possible financial structure in place to support the business that will both allow for flexibility in times of volatility and strengthen our balance sheet; that we will conduct a thorough review of our cost structure to identify areas for improvement, aiming to bring costs in line with peers, focusing on both capital expenditures and expenses and how that goal will be achieved; that we will seek to divest non-core properties, if the market conditions are favorable, and redeploy proceeds to growing our Cardium production; the next phases of our Cardium program including locations and timing; how we expect to further rationalize the portfolio to focus the Company towards light oil production and higher margin production; that a conservative hedging strategy will help provide certainty to our cash flow and capital programs for 2019 and 2020 hedging and combined with our capital flexibility improves our ability to live within FFO, while offering investors exposure to improving commodity prices; that we will work towards building a 2020 position and how the hedging contracts will be structured; our drilling plans, locations and focuses; our total planned capital for 2019 and that it remains flexible, with the ability to increase development activity should pricing allow; the guidance for production, operating costs, G&A and production growth; and the date, time, place of our Meeting and Corporate presentation to be conducted therein.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein; the impact of the Alberta mandated production curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, May 2, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is expected to release its first quarter 2019 financial and operational results before North American markets open on Friday, May 10, 2019. In addition, the first quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov in due course.
CONFERENCE CALL & WEBCAST DETAILS
Following the release of the 2019 first quarter financial and operational results, management will host a conference on Friday, May 10, 2019 at 8:00 am Mountain Time (10:00 am Eastern Time).
This call will be broadcast live on the Internet and may be accessed directly at the following URL: https://event.on24.com/wcc/r/1987019/B3F76468AE05747C94D06D589277AF19
Alternatively, to listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free).
A question and answer session will be held following managements' remarks for analysts and institutional investors.
A digital recording will be available for replay two hours after the call's completion, and will remain available until May 24, 2019, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 9795396, followed by the pound (#) key.
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SOURCE Obsidian Energy Ltd.
CALGARY, April 16, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce an operational update on our Cardium drilling program.
"While still in the early days of my tenure as Interim President and CEO of Obsidian Energy, I continue to be excited by the high caliber of our Cardium program and the future for long term growth. We continued to march through our development program delivering volumes as expected, on time, and on budget. Given the vast inventory of similar locations in Willesden Green and throughout our Cardium properties, we see years of compelling repeatable development campaigns to come. We are examining every facet of the business to ensure we are always making improvements, including a continual review of our capital allocation, cost structure, and portfolio composition." commented Michael Faust, Interim President and CEO.
Continued Cardium Success
After proving the viability of a quick cycle, light oil, primary production campaign in early 2018, we began a dedicated execution program starting in July 2018 and carrying through to break-up in March 2019. All 19 wells have now been completed and are on production. These wells continue to perform as expected, demonstrating the repeatability of our development style as we drill the first of several core Cardium areas. The average drill, complete, equip, and tie-in costs of all 19 wells came in at $3.8 million per well and without any safety or environmental incidents.
The 14 wells drilled in 2018 averaged initial production rates over the first 30 days of 540 boe per day and 87% oil. The 2019 portion of that program included five wells, the last three of which came on production in the past week. These three wells are showing extremely robust initial production rates, with the pad averaging single day peak rates of over 1,000 boe per day per well.
The Company will resume drilling of its fast cycle primary development program in the Cardium following spring break-up in July 2019 and plan to continue through to March 2020. All of our planned 2019 locations will be fully licensed and drill ready in the very near future. We remain committed to execute our program and keep our spend within Funds Flow from Operations, and therefore will remain flexible and responsive to changes in commodity price.
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. Please note that initial production and or peak rates are not necessarily indicative of long-term performance or ultimate recovery. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the potential for long term growth and inventory for repeatable compelling development; the expected full cycle IRRs; when we expect to resume drilling and duration; that all of our planned 2019 locations will be fully licensed and drill ready; and that we remain committed to execute our program and keep our spend within Funds Flow from Operations and remain flexible and responsive to changes in commodity prices.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Alberta Government curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, March 7, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", "we", "us" or "our") announces that it has filed with Canadian securities regulatory authorities its audited Consolidated Financial Statements for the year ended December 31, 2018 and related Management's Discussion and Analysis. Obsidian Energy has also filed its Annual Information Form for the year ended December 31, 2018, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101. Obsidian Energy's Annual Report on Form 40-F for the year ended December 31, 2018 will be filed with the U.S. Securities and Exchange Commission pursuant to its rules and regulations.
Copies of these documents may be obtained electronically via www.sedar.com and www.sec.gov/edgar.shtml (for the Form 40-F) or through Obsidian Energy's website at www.obsidianenergy.com. Hard copies of Obsidian Energy's audited Consolidated Financial Statements and related MD&A are also available upon request, free of charge, by contacting our Investor Relations group or by requesting them through our website.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and on the New York Stock Exchange under the symbol "OBE.BC".
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SOURCE Obsidian Energy Ltd.
CALGARY, March 7, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") today announced the appointment of Michael J. Faust as interim President and CEO, effective March 18, 2019 for a period of twelve months with an optional six-month extension. Mr. Faust will succeed current President and CEO, David French, who will step down from the Company effective March 29, 2019. Mr. French will not stand for reelection as a director at the Company's Annual General Meeting.
Mr. Faust has been a member of Obsidian's Board of Directors ("Board") since April 6, 2018. He has 35 years' experience within the oil and gas sector, including diverse geological, geophysical and technical reservoir experience spanning many different basins and formations throughout the world. Mr. Faust previously served as Vice President, Exploration and Land at ConocoPhillips Canada Ltd. and ConocoPhillips Alaska, Inc., prior to his retirement in January 2017.
"Mike's strong leadership and technical skills will be a great asset as we sharpen our focus on developing Obsidian's world-class Cardium assets," said Gord Ritchie, Chair of the Board. "The Board and I are confident that with Mike's leadership we can make uninterrupted progress on executing our strategic plan for 2019."
"I have been extremely impressed by Obsidian Energy's staff as well as their enviable acreage position in the Cardium and believe the drilling results in the back half of 2018 indicate that we are on the right track," said Mr. Faust. "My goal is to build on that momentum and continue the work of establishing Obsidian as a leading Cardium-focused company with a strong balance sheet and superior growth prospects."
Mr. Faust has a Master of Arts degree in Geophysics from the University of Texas and a Bachelor of Science degree in Geology from the University of Washington. Mr. Faust is a Certified Petroleum Geologist and a member of the American Association of Petroleum Geologists, and the Society of Exploration Geophysicists.
The Company also announced that it is bringing Development and Operations together under one department lead, Aaron Smith, to further streamline decision-making and enhance efficiencies. Mr. Smith will assume the position of Senior Vice President of Development and Operations. Mr. Smith joined the Company in July 2018 and brings over 20 years of engineering expertise across a broad range of technical and leadership roles. He has played an instrumental role in the recent success of the Company's drilling program.
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SOURCE Obsidian Energy Ltd.
CALGARY, March 7, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its year-end 2018 financial and operational results. All figures are in Canadian dollars unless otherwise stated. Obsidian Energy's audited consolidated financial statements and Management's Discussion and Analysis ("MD&A") as at and for the year-ended December 31, 2018 can be found on our website at www.obsidianenergy.com. The documents will also be filed on SEDAR and EDGAR in due course.
"Obsidian Energy implemented a manufacturing drilling model in the Cardium in the second half of 2018 that delivered significant cost efficiencies and demonstrable year-end reserve growth," commented David French, President and CEO. "And while the widening differentials weighed on financial results for the quarter, as it did across the industry, the success of our efforts in the Cardium have set the foundation for 2019 and beyond."
"We entered 2019 with a clear focus on prioritizing primary, short cycle, light oil Cardium development. Given the depth of our inventory and our disciplined approach to managing our non Cardium portfolio, we have the scale and flexibility for significant growth as oil prices strengthen. Because of the Alberta Government Curtailment Rules, the first half of 2019 is dedicated to ensuring the highest netback barrels are produced within our allocation. We intend to spend within funds flow from operations and maintain a portfolio of drill ready locations. We look forward to building upon the successes in the Cardium and are excited for the future it represents."
"Having made further progress on reshaping our legacy portfolio and demonstrated the value of our approach to the Cardium, I feel now is the appropriate time to transition the Company to new leadership," added Mr. French. "It has been a privilege to work with the Board and Obsidian Energy's dedicated staff during the Company's pivot to new growth. I have great confidence in the team and the Company's future." Mr. French will step down from the Company on March 29, 2019. Michael J. Faust has been named interim President and CEO, effective March 18, 2019.
"We would like to thank Dave for his positive contributions. He led the Company through its strategic transition towards the Cardium and materially reduced the costs of the legacy portfolio, which helps position the Company for success," said Gord Ritchie, Chair of the Board. "We appreciate Dave's efforts and wish him well in the future."
"I would like to express my gratitude and appreciation to the staff and Board at Obsidian Energy for everyone's efforts during my time as President and CEO," said Mr. French. "I wish Mike every success in his new role as he guides the Company towards its refocused strategy."
Please see accompanying press release for additional information.
Leading Drilling Results
The Company drilled 20 gross operated Cardium producing wells throughout the year, with 10 of the 14 second half 2018 ("H218") program wells being brought online before the end of the year. These H218 wells have achieved high initial production rates, with high liquids weighting, that are meeting our initial expectations while costs are below budget. The Company has successfully yielded IP30 rates between 328 and 860 boe per day and capital efficiencies of approximately $18,500 per boe which remain competitive across the Western Canadian sedimentary basin. The strong results of the H218 Cardium drilling program emphasizes the potential of the Willesden Green asset which will be the main pillar of the Company during 2019.
In addition to the Cardium program, the Company successfully drilled eight gross wells in the Peace River Oil Partnership ("PROP") area, four of which were brought on production in the first half of 2018. These four wells have reached some of the highest rates ever achieved in the area. Due to improved Western Canadian Select differentials in early 2019, the Company has decided to bring the remaining four wells on production. The Company also continued its delineation of the Deep Basin play and successfully drilled two development wells in 2018.
Achieved 2018 Production and Capital Guidance
Full year 2018 production was 28,953 boe per day, on the high end of our revised guidance range of 28,500 – 29,000 boe per day, despite spending $13 million less than our estimated full year revised capital guidance of $190 million. In the fourth quarter of 2018, the Company achieved production of 29,905 boe per day, which represents eight percent production growth over the third quarter of 2018. Our 2018 optimization program continued to maintain our shallow base decline and solid execution of our second half development program led to the strong performance in the quarter.
Full year 2018 capital expenditures were $168 million plus $9 million of decommissioning expenditures. This is well below our guidance, demonstrating our ability to manage capital in a difficult pricing environment. Total capital included 36 gross operated wells and the completion of Alberta Energy Regulator's ("AER") Directive 84 to build a gas gathering plant and associated infrastructure for Hydrocarbon Emission Controls and Gas Conservation in the Peace River area. Fourth quarter capital expenditures were $41 million, which included drilling 10 Willesden Green Cardium wells and one PROP well.
Lowest Quarterly Cost Structure Realized in More Than 10 years
Fourth quarter 2018 operating expenses were $33 million or $11.82 per boe and general and administrative costs were $5 million or $1.95 per boe. The reduction was due to increasing Cardium volumes and successful cost saving initiatives in the quarter. This represents the best operating and general and administrative costs per boe realized by the Company in more than 10 years.
Full year operating expenses were $147 million or $13.89 per boe, a decrease of $29 million versus full year 2017, comfortably within our revised guidance range of $13.75 – $14.00 per boe. Full year general and administrative costs were $24 million or $2.24 per boe. This represents a decrease of $7 million versus full year 2017 and is at the mid-point of our guidance range of $2.00 – $2.50 per boe. The Company will continue to focus on additional cost saving initiatives in 2019.
Second Half Optionality Remains to Enhance 2020 Outlook
Given the volatility of Alberta commodity prices, the Company has maintained the operational flexibility to adjust our second half 2019 capital program. Obsidian Energy has a large inventory of highly economic, drill ready locations and plenty of infrastructure head room to facilitate growth. We will continue to be prudent with respect to balance sheet management, targeting balanced capital spending to Funds Flow from Operations ("FFO"). As next quarter's pricing plays out and we obtain further certainty on our full year cash flow profile, we will fine tune our capital program for the second half of the year.
Decreasing Decommissioning Liabilities with Cost Reductions
Obsidian Energy has been actively managing our ongoing liability for many years by approaching well, pipeline, and facility abandonments on a systematic basis. In 2018, the Company elected to participate in the AER's Area Based Closure Program ("ABC") and began the shut-in of our marginal Legacy portfolio. Obsidian Energy was able to shut-in a significant portion of its Legacy properties at minimal cost to the Company which will result in a reduction in our Legacy operating costs by an additional $4 million in 2019. Additionally, due to this activity we were able to reduce our overall Decommissioning Liability by approximately $24 million on a discounted basis versus the third quarter of 2018 due in part to these successful initiatives. We plan to continue this momentum into 2019 and target to reduce the average cost of abandoning wells by approximately 30 percent.
Financial and Operating Highlights
Three months ended December 31 | Year ended December 31 | ||||||||||
2018 | 2017 | % change | 2018 | 2017 | % change | ||||||
Financial (millions, except per share amounts) | |||||||||||
Funds Flow from Operations (1) | $ | (2) | $ | 52 | >(100) | $ | 92 | $ | 192 | (52) | |
Basic per share (1) | - | 0.10 | (100) | 0.18 | 0.38 | (53) | |||||
Diluted per share (1) | - | 0.10 | (100) | 0.18 | 0.38 | (53) | |||||
Net loss | (113) | (58) | (95) | (305) | (84) | >(100) | |||||
Basic per share | (0.22) | (0.12) | (83) | (0.60) | (0.17) | >(100) | |||||
Diluted per share | (0.22) | (0.12) | (83) | (0.60) | (0.17) | >(100) | |||||
Capital expenditures (2) | 41 | 37 | 11 | 168 | 141 | 19 | |||||
Net Debt (1) | $ | 497 | $ | 383 | 30 | $ | 497 | $ | 383 | 30 | |
Operations | |||||||||||
Daily production | |||||||||||
Light oil and NGL (bbls/d) | 14,217 | 14,288 | - | 13,752 | 14,236 | (3) | |||||
Heavy oil (bbls/d) | 4,784 | 5,247 | (9) | 4,885 | 5,387 | (9) | |||||
Natural gas (mmcf/d) | 65 | 71 | (8) | 62 | 73 | (15) | |||||
Total production (boe/d) (3) | 29,905 | 31,447 | (5) | 28,953 | 31,723 | (9) | |||||
Average sales price | |||||||||||
Light oil and NGL (per bbl) | $ | 35.35 | $ | 62.70 | (44) | $ | 61.85 | $ | 56.84 | 9 | |
Heavy oil (per bbl) | 7.70 | 38.12 | (80) | 33.07 | 33.27 | (1) | |||||
Natural gas (per mcf) | $ | 2.46 | $ | 2.51 | (2) | $ | 2.21 | 2.81 | (21) | ||
Netback per boe (3) | |||||||||||
Sales price | $ | 23.42 | $ | 40.55 | (42) | $ | 39.45 | $ | 37.58 | 5 | |
Risk management gain | (3.84) | - | >(100) | (6.10) | 2.02 | >(100) | |||||
Net sales price | 19.58 | 40.55 | (52) | 33.35 | 39.60 | (16) | |||||
Royalties | (2.33) | (2.64) | (12) | (3.40) | (2.57) | 32 | |||||
Operating expenses (4)(5) | (11.82) | (14.40) | (18) | (13.89) | (15.18) | (8) | |||||
Transportation | (3.45) | (2.41) | 43 | (3.39) | (2.48) | 37 | |||||
Netback (1) | $ | 1.98 | $ | 21.10 | (91) | $ | 12.67 | $ | 19.37 | (35) |
(1) | The terms "funds flow from operations" and their applicable per share amounts, "netback", and "net debt" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. | |
(2) | Includes the benefit of capital carried by partners in 2017. | |
(3) | Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". | |
(4) | Includes the benefit of processing fees totaling $11 million for 2018 (2017 - $13 million). | |
(5) | Operating costs per boe is presented excluding the impact of carried operating expenses in 2017. The benefit of carried operating expenses from the Company's partner under the PROP was fully utilized in December 2017. For 2017, the benefit of carried operating expenses from the Company's partner under the PROP was $21 million ($1.78 per boe). |
Area | Select Metrics – Three Months Ended December 31, 2018 | ||||
Production | Liquids | Operating | Netback | ||
Cardium | 19,466 boe/d | 66% | $11/boe | $11/boe | |
Deep Basin | 1,929 boe/d | 20% | $3/boe | $12/boe | |
Alberta Viking | 1,430 boe/d | 46% | $16/boe | $5/boe | |
Peace River | 5,245 boe/d | 88% | $10/boe | $(9)/boe | |
Key Development Areas | 28,070 boe/d | 66% | $11/boe | $7/boe | |
Legacy Areas | 1,835 boe/d | 27% | $28/boe | $(13)/boe | |
Key Development & Legacy Areas | 29,905 boe/d | 64% | $12/boe | $6/boe |
The table below provides a summary of our operated activity in the fourth quarter.
Number of Wells Q4 2018 | ||||||||
Drilled | Completed | On stream | ||||||
Gross | Net | Gross | Net | Gross | Net | |||
Cardium | ||||||||
Producer | 10 | 10.0 | 10 | 10.0 | 10 | 10.0 | ||
Injector | 0 | 0.0 | 0 | 0.0 | 0 | 0.0 | ||
Deep Basin | 0 | 0.0 | 0 | 0.0 | 0 | 0.0 | ||
Alberta Viking | 0 | 0.0 | 0 | 0.0 | 0 | 0.0 | ||
Peace River | 1 | 0.6 | 2 | 1.1 | 2 | 1.1 | ||
Total | 11 | 10.6 | 12 | 11.1 | 12 | 11.1 |
Updated Hedging and Marketing Position
Currently, the Company has the following crude oil hedges in place:
Q1 2019 | Q2 2019 | |
WTI $USD | $50.02 | $56.53 |
bbl/day | 3,000 | 2,000 |
WTI $CAD | $67.88 | $68.58 |
bbl/day | 6,000 | 4,000 |
Total | ||
bbl/day | 9,000 | 6,000 |
In late 2018, the decrease in crude oil prices allowed the Company to restructure part of its existing hedge book by removing a 1,000 barrel per day WTI swap in the third quarter of 2019 for proceeds of $0.5 million.
In the first quarter of 2019, the Company has foreign exchange contracts at an average of 1.300 on notional US$2 million per month. Currently, the Company has no natural gas hedges in place.
In late December, the Company also monetized the physical delivery contract for 15 mmcf per day to Northern Border Ventura for US$10.5 million or CAD$14 million. The decision to monetize the contract was due to an expansion in the forward curve spread between AECO and Northern Border Ventura gas pricing.
2019 Guidance Summary
Our total 2019 guidance remains unchanged.
Production and Cost Guidance:
Metric | 2019 Guidance Range |
Production | 26,750 to 27,750 boe per day |
Capital Expenditures including | $120 million |
Production Growth Rate (1) | Flat |
Operating Costs | $14.00 - $14.50 per boe |
General & Administrative | $2.00 - $2.50 per boe |
(1) Relative to full year 2018 production adjusted of 26,900 boe per day for shut in volumes and Carrot Creek Disposition |
Carrot Creek Disposition
In the first quarter of 2019, the Company signed a purchase and sale agreement to sell the associated production and mineral rights below the Cardium formation from its Carrot Creek property for $12.5 million. Production from the asset is estimated to be approximately 460 boe per day (72% gas weighted) in 2019. This divestiture is consistent with the Company's focus on the Cardium formation, to which it retains the rights. The proceeds of this transaction will be used to pay down our syndicated credit facility. Transaction metrics are outlined below.
Transaction Metrics | |
Transaction Value | $12.5 million |
Production (1) | 460 boe/d (72% gas) |
Implied Production Multiple | $27,000/boe |
Net Operating Income (NOI) (2) | $2.1 million |
Implied NOI Multiple | 6.0x |
(1) | Production numbers are based on estimated full year 2019 volumes |
(2) | NOI is estimated using strip pricing for full year 2019 as of March 1, 2019 |
Covenant Amendment
In March 2019, the Company reached an agreement with the holders of our senior notes to amend our Senior and Total Debt to Adjusted EBITDA covenants for 2019. The amendment provides flexibility to execute the 2019 program within covenant levels.
The Senior Debt and Total Debt to Adjusted EBITDA covenants will be set at a maximum of 4.25:1 for 2019. The Adjusted EBITDA calculation will be based on a rolling EBITDA basis, resetting on January 1, 2019. As part of the agreement, the Company agreed to pay an additional 50 bps if the covenant is less than or equal to 3.00:1, 100 bps if the covenant is greater than 3.00:1 and less than or equal to 4.00:1 and 150 bps if the covenant is greater than 4.00:1 and less than or equal to 4.25:1.
On January 1, 2020, the covenants will revert to the maximum ratios required prior to entering into the amending agreements (Senior Debt to Adjusted EBITDA - 3:1, Total debt to Adjusted EBITDA - 4:1).
Proposed Share Consolidation
The Board of Directors ("Board") has unanimously concluded that a proposal of a share consolidation of Obsidian Energy's common shares is in the best interest of the Company and its shareholders. The share consolidation will reduce the outstanding equity float to a level more in line with the Company's peers and eliminate uncertainty regarding the Company's plan to maintain its New York Stock Exchange ("NYSE") listing. The proposed consolidation ratio will likely ensure continued compliance with the NYSE's minimum share price listing requirement and reduced transaction costs for lot trading.
Stephen Loukas, a member of the Obsidian Energy Board and a Partner in one of the Company's largest shareholders, stated "After thorough analysis and consideration, the Board has concluded that there is value in maintaining the Company's listing on the NYSE, particularly in light of the significant ownership in Obsidian Energy's shares by U.S. based investors. We believe maintaining the U.S. listing supports the Board's goal of closing the gap between the Company's current trading price and intrinsic value."
Shareholders will be asked to pass a special resolution that will authorize the Board of Directors to direct the Company to amend our articles, in order to consolidate the Company's issued common shares into a lesser number of issued common shares on the basis of seven (7) old common shares for one (1) new common share. The Board of Directors will retain the discretion to revoke the share consolidation resolution and elect not to proceed with the filing of the articles of amendment and the implementation of the share consolidation.
A share consolidation will be subject to approval of the Toronto Stock Exchange and the NYSE. Further information regarding the potential share consolidation and timing of the Annual and General Meeting will be included in the Company's Management Information Circular to be disseminated later this spring. The Company's shares will continue to trade on the NYSE during this time and until after the consolidation proposal has been addressed at the Annual General Meeting.
Year-End 2018 Financial Results Conference Call Details
A conference call will be held to discuss the results at 6:30 a.m. Mountain Time (8:30 a.m. Eastern Time) on March 7, 2019.
This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1950371/3519F2A1554A7061A1AF05ADB846B41C
Alternatively, to listen to the conference call, please call 403-451-9838 or 1-888-231-8191 (toll-free).
A questions and answer session will be held following Managements' remarks for analysts and institutional investors.
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 21, 2019, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 4193633, followed by the pound (#) key.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
Certain financial measures including funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, net debt and Adjusted EBITDA, included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures, office lease settlements, the effects of financing related transactions from foreign exchange contracts and debt repayments and certain other expenses and is representative of cash related to continuing operations. Funds flow from operations is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of funds flow from operations to cash flow from operating activities, being its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation expenses and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. Net debt is the total of long-term debt and working capital deficiency and is used by the Company to assess its liquidity. Adjusted EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayment, restructuring expenses and other expenses. Adjusted EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation.
Calculation of Funds Flow from Operations
Year ended December 31 | |||||
(millions, except per share amounts) | 2018 | 2017 | |||
Cash flow from operating activities | $ | 99 | $ | 125 | |
Change in non-cash working capital | (68) | (5) | |||
Decommissioning expenditures | 9 | 16 | |||
Office lease settlements | 13 | 16 | |||
Settlements of normal course foreign exchange contracts | 3 | (8) | |||
Realized foreign exchange loss – debt maturities | 8 | 6 | |||
Realized foreign exchange loss – hedging repayment (1) | 18 | - | |||
Restructuring charges (2) | 8 | 10 | |||
Other expenses (3) | 16 | 11 | |||
Monetization of transportation contract (4) | (14) | - | |||
Carried operating expenses (5) | - | 21 | |||
Funds flow from operations | $ | 92 | $ | 192 | |
Per share – funds flow from operations | |||||
Basic per share | $ | 0.18 | $ | 0.38 | |
Diluted per share | $ | 0.18 | $ | 0.38 |
(1) | During the third quarter of 2018, the Company's outstanding GBP cross currency swap matured resulting in an $18 million realized loss. |
(2) | In 2018, excludes the non-cash portion of restructuring totaling $8 million, on payments due in 2019 and 2020. |
(3) | In 2018, includes legal fees related to ongoing claims against former Penn West Petroleum ("Penn West") employees related to the Company's 2014 restatement of certain financial results. In 2017, the Company settled the outstanding lawsuit it had with the United States Securities and Exchange Commission ("SEC") for US$8.5 million (CAD$11 million) during the fourth quarter. |
(4) | In the fourth quarter of 2018, the Company monetized a physical delivery contract on 15 mmcf of natural gas per day to Northern Border Ventura for US$10.5 million (CAD$14 million) |
(5) | The benefit of carried operating expenses from the Company's partner under the PROP was fully utilized in December 2017. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the 2019 guidance for production, capital expenditure including decommissioning expenditures, production growth grate, operating and general and administrative cost ranges; that the MD&A and audited financial statements will be filed on our website, SEDAR and EDGAR in due course; that the success of our effects in the Cardium have set the foundation for 2019 and beyond; that we have the scale and flexibility for significant growth as oil prices strengthen; that due to the Alberta Government Curtailment Rules, the first half of 2019 is dedicated to ensuring the highest netback barrels are produced within our allocation; that we intend to spend within FFO and maintain a portfolio of drill ready locations; that the Willesden Green asset will be the main pillar of the Company during 2019; our intentions regarding development and bringing certain wells online; that the Company will continue to focus on additional further cost saving initiatives in 2019; that we have operational flexibility to adjust our second half 2019 capital program; that we will continue to be prudent with respect to balance sheet management, targeting balanced capital spending to FFO; that we will fine turn our capital program for the second half of the year; our expected capital saving through taking part in ABC; that we will target to reduce the average cost of abandoning wells by approximately 30 percent; the use of proceeds for the Carrot Creek disposition; that the amendment provides flexibility to execute the 2019 program within covenant levels; what we expect the covenants to revert to on January 1, 2020; that the share consolidation will reduce the outstanding equity float to a level more in line with the Company's peers and eliminate uncertainty regarding the Company's plan to maintain its NYSE listing; that the proposed consolidation ratio will likely ensure continued compliance with the NYSE's minimum share price listing requirement and reduced transaction costs for lot trading; that there is value in maintaining the NYSE listing; the belief that maintaining the U.S. listing supports the Board's goal of closing the gap between the Company's current trading price and intrinsic value; that shareholders will be asked to pass a special resolution at the Annual General Meeting in connection with the share consolidation; that the Board of Directors will retain the discretion to revoke the share consolidation resolution and elect not to proceed with the filing of the articles of amendment and the implementation of the share consolidation; and that the Company will disseminate its Management Information Circular later this Spring; and that the Company's shares will continue to trade on the NYSE during this time and until after the consolidation proposal has been addressed at the Annual General Meeting.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of the Albert Government curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, March 1, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is expected to release its financial and operational results for the year ended December 31, 2018 before North American markets open on Thursday, March 7, 2019. In addition, the year ended management's discussion and analysis and the audited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
CONFERENCE CALL & WEBCAST DETAILS
A conference call will be held to discuss the results at 6:30 am Mountain Time (8:30 am Eastern Time) on Thursday, March 7, 2019.
To listen to the conference call, please call 403-451-9838 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1950371/3519F2A1554A7061A1AF05ADB846B41C
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 21, 2019, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 4193633, followed by the pound (#) key.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and on the New York Stock Exchange under the symbol "OBE.BC".
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SOURCE Obsidian Energy Ltd.
CALGARY, Feb. 21, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces that Gordon Ritchie will replace Jay W. Thornton as Chairman of the Board of Directors (the "Board"). Mr. Thornton has resigned his Board position effective as of the close of business on Wednesday, February 20, 2019 due to personal reasons.
Mr. Ritchie commented "I would like to thank Jay for his time on the Board and acting as Chairman. As I embark in this new role as Chairman, I look forward to working with the Board to provide continuing support to the leadership team in executing the Company's strategy. Obsidian's business plan will continue to be primarily Cardium focused, with the objective of returning Obsidian Energy to long-term, sustainable growth."
Mr. Thornton said "I would like to express my appreciation to the Board and management of Obsidian Energy for all of their support during my time as a director and wish them all the best."
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE" and "OBE.BC" respectively.
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SOURCE Obsidian Energy Ltd.
CALGARY, Feb. 11, 2019 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to release its year-end 2018 independent reserves evaluation and provide Company updates on our recent drilling results, marketing and hedging portfolio, 2019 development and guidance revisions.
2018 Year-End Reserves Summary
The Company is pleased to present the results of its year-end 2018 independent reserves evaluation, prepared by Sproule Associates Limited ("Sproule").
2018 marks the second year in a row that Obsidian Energy has achieved greater than 100 percent reserve replacement on proved plus probable ("2P") and total proved reserves ("1P"). This increase is a direct result and recognition of the performance of our 2018 Cardium drilling program with a 1P and 2P reserve replacement in the Cardium of approximately 150 and 140 percent respectively. Our Cardium assets in Willesden Green continue to perform with 16 additional undeveloped locations added to our book's primary Cardium count. The Company also continues to see benefits from its optimization and decline mitigation projects with an average three year proved developed producing ("PDP") decline of 15.8 percent. We are excited about the future development opportunities, particularly in our Cardium assets, which will allow us to create long term value for our shareholders.
Reserve Highlights:
Cardium Drilling Program Update
All 14 wells of the second half 2018 Cardium program have been drilled and completed with 12 currently on production. Well performance on average is exceeding the updated type-curves presented at our Investor Day on November 15, 2018. The Company's focus on cost reduction has resulted in an average well cost of $3.6 million on the first 14 wells, significantly below forecasted cost estimates. The final two wells off the 5-18 pad have been fractured, with one well setting a record for the Company's longest Cardium well drilled to date at 5,290 meters of measured depth with 38 fracture stages. These two wells will be on production by mid-February.
Early rate performance of the wells is shown below. Aggregate production from the program has averaged approximately 3,620 barrels of oil per day and 4,693 boe per day in the last 30 days.
Pad | Status | Deliverability |
8-9 (3 wells) | On production | Average IP30 per well: 621 boepd (76% oil); IP60 per well: 477 boepd (71% oil) |
14-1 (2 wells) | On production | Average IP30 per well: 433 boepd (85% oil); IP60 per well: 338 boepd (84% oil) |
4-6 (3 wells) | On production | Average IP30 per well: 527 boepd (91% oil); IP60 per well: 563 boepd (84% oil) |
1-36 (2 wells) | On production | Average IP30 per well: 672 boepd (90% oil) |
9-2 (2 wells) | On production | Average IP10 per well: 502 boepd (90% oil) |
5-18 (2 wells) | Fracturing complete | Production expected mid-February |
Marketing and Hedging Portfolio Update
In late December, the Company monetized the physical delivery contract for 15,000 mmcf per day to Northern Border Ventura for US$10.5 million or CAD$14 million. The decision to monetize the contract was due to an expansion in the forward curve spread between AECO and Northern Border Ventura gas pricing.
The recent downward swing in oil prices also allowed the Company to restructure part of its existing hedge book by removing a 1,000 barrel a day WTI swap in the third quarter of 2019 for cash to Obsidian Energy of approximately $500,000.
2019 Development and Revised Guidance
In early December, the Alberta Government announced a mandatory curtailment program ("Curtailment") to relieve excess supply of crude oil and bitumen in Western Canada. Since the announcement, there has been a meaningful contraction of Canadian differentials improving the outlook for Western Canadian producers. Obsidian Energy is supportive of these actions and views them as a near-term positive step for the energy industry in Western Canada.
In light of the Curtailment, Obsidian Energy has elected to defer a four-well pad with two Cardium wells and two Deep Basin wells to the second half of 2019. The deferral will reduce first half 2019 capital expenditures by approximately $20 million to $45 million. Our first half 2019 drilling program now consists of five Willesden Green Cardium wells which is underway with production expected near the end of March.
Based on preliminary estimates, the Company expects first quarter 2019 light and heavy oil production to be approximately 15,750 – 16,250 barrels per day net to Obsidian Energy, which reflects the curtailment requirements for the quarter. Total production for the first quarter of 2019, including natural gas liquids and natural gas is expected to be approximately 27,000 – 27,500 boe per day net to Obsidian Energy. Currently, the Company has approximately 2,200 boe per day behind pipe and if the Curtailment requirements were to be lifted or reduced, we would bring those volumes on production.
The full year 2019 optimization budget has been reduced by $3 million in favour of adding one Willesden Green Cardium well to the second half 2019 drilling program for a total of 16 Willesden Green Cardium wells and two Deep Basin wells with no changes to our full year capital estimate. The Company continues to evaluate its capital allocation decisions on an ongoing basis. At this time, we view the servicing of our credit facility and the Cardium development in Willesden Green as the most prudent use of investment dollars in our portfolio.
Due to mandated Curtailments and the decision to shift capital into the second half of 2019, Obsidian Energy is revising its guidance for full year production and growth rates. With reduced volumes, there will be follow-on affects to operating and general & administrative cost per boe. Obsidian Energy's guidance assumes the Curtailment will remain throughout 2019 but continues to ease over the course of the year.
Production and Cost Guidance:
Metric | Previous 2019 Guidance Range | Updated 2019 Guidance Range |
Production | 28,000 to 29,000 boe per day | 26,750 to 27,750 boe per day |
Capital Expenditures including | $120 MM | No change |
Production Growth Rate (1) | 3%-6% | Flat |
Operating Costs | $13.00 - $13.50 per boe | $14.00 - $14.50 per boe |
General & Administrative | $1.75 - $2.25 per boe | $2.00 - $2.50 per boe |
(1) Relative to projected full year 2018 production (using midpoint of guidance), adjusted for shut in volumes, of |
Capital Program Details:
Capital Category | # of Wells | Net Capital |
Cardium | 16 Producers | $74 million |
Deep Basin | 2 Producers | $7 million |
Non-Operated Primary Drilling | 2.5 net Producers | $6 million |
Existing Wellbore Optimization | >25 Projects | $5 million |
Maintenance & Corporate | $16 million | |
Capital Expenditures | $108 million | |
Decommissioning Expenditures | $12 million | |
Total | $120 million |
2018 Year-End Reserves Tables
In 2018, we engaged Sproule, an independent, qualified engineering firm, to evaluate 100 percent of our 1P and 2P reserves. Sproule conducted an independent reserves evaluation of Obsidian Energy's reserves effective December 31, 2018. This evaluation was prepared in accordance with definitions, standards, and procedures set out in Canadian Oil and Gas Evaluation Handbook ("COGEH") and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). The Sproule reserves evaluation was based on Sproule's December 31, 2018 forecast prices and costs. Reserves included below are Company gross reserves which are the Company's total working interest reserves before the deduction of any royalties and excluding any royalty interests payable to the Company. The numbers in the tables below may not add due to rounding.
Summary of Reserves
As at December 31, 2018 | |||||
Reserve | Light & | Heavy | Natural Gas | Conventional | Barrel of Oil |
Estimates Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Proved | |||||
Developed producing | 33 | 6 | 6 | 131 | 66 |
Developed non-producing | 1 | 0 | 0 | 3 | 2 |
Undeveloped | 14 | 1 | 2 | 41 | 24 |
Total Proved | 47 | 7 | 8 | 176 | 92 |
Total Probable | 17 | 4 | 3 | 57 | 33 |
Total Proved plus Probable | 64 | 11 | 11 | 233 | 125 |
Reserves Reconciliation – Proved
Light & | Heavy | Natural Gas | Conventional | Barrel of Oil | |
Reconciliation Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Total Proved | |||||
December 31, 2017 | 47 | 8 | 8 | 194 | 96 |
Extensions | 2 | 0 | 1 | 13 | 5 |
Infill Drilling | 1 | 0 | 0 | 3 | 2 |
Improved Recovery | 0 | 0 | 0 | 0 | 0 |
Technical Revisions | 2 | 0 | 1 | 19 | 6 |
Discoveries | 0 | 0 | 0 | 0 | 0 |
Acquisitions | 0 | 0 | 0 | 0 | 0 |
Dispositions | (1) | 0 | (0) | (23) | (5) |
Economic Factors | 0 | 0 | (0) | (7) | (1) |
Production | (4) | (2) | (1) | (22) | (11) |
December 31, 2018 | 47 | 7 | 8 | 176 | 92 |
Reserves Reconciliation – Proved Plus Probable
Light & | Heavy | Natural Gas | Conventional | Barrel of Oil | |
Reconciliation Category | (mmbbl) | (mmbbl) | (mmbbl) | (bcf) | (mmboe) |
Total Proved Plus Probable | |||||
December 31, 2017 | 66 | 12 | 10 | 258 | 131 |
Extensions | 4 | 0 | 1 | 18 | 8 |
Infill Drilling | 1 | 0 | 0 | 3 | 2 |
Improved Recovery | 0 | 0 | 0 | 0 | 0 |
Technical Revisions | (1) | 0 | 1 | 14 | 2 |
Discoveries | 0 | 0 | 0 | 0 | 0 |
Acquisitions | 0 | 0 | 0 | 0 | 0 |
Dispositions | (1) | 0 | (0) | (31) | (7) |
Economic Factors | 0 | 0 | (0) | (8) | (1) |
Production | (4) | (2) | (1) | (22) | (11) |
December 31, 2018 | 64 | 11 | 11 | 233 | 125 |
Summary of Before Tax Net Present Values
As at December 31, 2018 | |||||
Net Present Value | Discount Rate | ||||
$ millions | Undiscounted | 5 Percent | 10 Percent | 15 Percent | 20 Percent |
Proved | |||||
Developed producing | 2,140 | 1,474 | 1,128 | 921 | 784 |
Developed non-producing | 43 | 33 | 26 | 22 | 19 |
Undeveloped | 592 | 285 | 140 | 63 | 17 |
Total Proved | 2,774 | 1,792 | 1,294 | 1,006 | 820 |
Total Probable | 1,417 | 674 | 408 | 282 | 212 |
Total Proved plus Probable | 4,191 | 2,466 | 1,702 | 1,288 | 1,032 |
Future Development Capital
As at December 31, 2018 | ||
Future Development Capital | ||
$ millions | Total Proved | Total Proved |
2019 | 112 | 117 |
2020 | 113 | 131 |
2021 | 118 | 155 |
2022 | 127 | 154 |
2023 | 42 | 61 |
2024 and subsequent | 0 | 0 |
Total, Undiscounted | 511 | 618 |
Total, Discounted @ 10% | 416 | 498 |
Summary of Pricing and Inflation Rate Assumptions
Canadian Light | Natural Gas | |||||||
WTI | Sweet Crude | AECO-C | Exchange | |||||
As at December 31, 2018 (1) | Cushing, Oklahoma | 40° API | Spot | Rate | ||||
Sproule Forecast | ($US/bbl) | ($Cdn/bbl) | ($Cdn/MMbtu) | ($US/$Cdn) | ||||
Year | 2018 | 2017 | 2018 | 2017 | 2018 | 2017 | 2018 | 2017 |
Forecast | ||||||||
2019 | 63.00 | 65.00 | 75.27 | 74.51 | 1.95 | 3.11 | 0.77 | 0.82 |
2020 | 67.00 | 70.00 | 77.89 | 78.24 | 2.44 | 3.65 | 0.80 | 0.85 |
2021 | 70.00 | 73.00 | 82.25 | 82.45 | 3.00 | 3.80 | 0.80 | 0.85 |
2022 | 71.40 | 74.46 | 84.79 | 84.10 | 3.21 | 3.95 | 0.80 | 0.85 |
2023 | 72.83 | 75.95 | 87.39 | 85.78 | 3.30 | 4.05 | 0.80 | 0.85 |
2024 | 74.28 | 77.47 | 89.14 | 87.49 | 3.39 | 4.15 | 0.80 | 0.85 |
2025 | 75.77 | 79.02 | 90.92 | 89.24 | 3.49 | 4.25 | 0.80 | 0.85 |
2026 | 77.29 | 80.60 | 92.74 | 91.03 | 3.58 | 4.36 | 0.80 | 0.85 |
2027 | 78.83 | 82.21 | 94.60 | 92.85 | 3.68 | 4.46 | 0.80 | 0.85 |
2028 | 80.41 | 83.85 | 96.49 | 94.71 | 3.78 | 4.57 | 0.80 | 0.85 |
2029 | 82.02 | 98.42 | 3.88 | 0.80 | ||||
(1) Prices Escalate at two percent after 2029, with the exception of foreign exchange which stays flat |
All figures contained in this release are in Canadian dollars unless otherwise noted.
The financial and operating information in this press release is based on estimates and is unaudited. Some of the terms below do not have standardized meanings. Further detail can be found in the "Oil and Gas Advisory" section contained in this release. Additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR, EDGAR, and posted to our website in March. All numbers are shown prior to the impact of 2019 disposition activity unless otherwise noted.
Oil and Gas Advisory
This press release contains a number of oil and gas metrics, including "FDC", "F&D costs", and "RLI" which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. FDC is the sum of all booked capital. F&D costs are the sum of exploration and development costs incurred in the period, plus the change in estimated FDC for the reserves category, all divided by the change in reserves during the period. F&D costs exclude the impact of acquisitions and divestitures. NPV per share, adjusted for debt, is synonymous for NAV, and is based on the present value of future net revenues discounted at 10% before tax, adjusted for unaudited net debt as at December 31, 2018. The NPV per share is divided by the number of Obsidian Energy shares outstanding as at December 31, 2018. RLI is calculated as total Company gross reserves divided by Sproule's forecasted 2019 production for the associated reserve category. Under NI 51-101, proved reserves estimates are defined as having a high degree of certainty to be recoverable with a targeted 90 percent probability in aggregate that actual reserves recovered over time will equal or exceed proved reserve estimates. For proved plus probable reserves under NI 51-101, the targeted probability is an equal (50 percent) likelihood that the actual reserves to be recovered will be greater or less than the proved plus probable reserve estimate. The reserve estimates set forth above are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein.
Non-GAAP
Certain financial measures including net debt included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Net Debt includes long-term debt and includes the effects of working capital and all cash held on hand.
Abbreviations Contained in the Press Release
Oil and Natural Gas Liquids | Natural Gas | ||
bbl | barrel or barrels | GJ | gigajoule |
bbl/d | barrels per day | GJ/d | gigajoules per day |
mbbl | thousand barrels | mcf | thousand cubic feet |
mmbbl | million barrels | mmcf | million cubic feet |
NGLs | natural gas liquids | bcf | billion cubic feet |
mmboe | million barrels of oil equivalent | mcf/d | thousand cubic feet per day |
mboe | thousand barrels of oil equivalent | mmcf/d | million cubic feet per day |
boe/d | barrels of oil equivalent per day | m3 | cubic metres |
mmbtu | million British thermal units |
Other | |
AECO | the Alberta benchmark price for natural gas. |
BOE or | barrel of oil equivalent, using the conversion factor of 6 mcf of natural gas being equivalent to one barrel of oil. |
WTI | West Texas Intermediate, the reference price paid in United States dollars at Cushing, Oklahoma for crude oil of standard grade. |
API | American Petroleum Institute. |
°API | the measure of the density or gravity of liquid petroleum products derived from a specific gravity. |
MM$ | million dollars. |
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we are excited about the future development opportunities, specifically in our Cardium assets, which will allow us to create long term value for our shareholders; expectations for when certain wells will come online; our expectations for deferring certain wells, when they are expected to come online, the impact those actions have on first half 2019 expenditures and drilling program and on production dates; our expectation for first quarter 2019 light and heavy oil production, and total production net to Obsidian Energy, which reflects that curtailment requirements for the quarter; when we will bring certain volumes on after the curtailment requirements are lifted; that the Company continues to evaluate its capital allocation decisions on an ongoing basis; the updated 2019 guidance for production, capital expenditure including decommissioning expenditures, production growth grate, operating and general and administrative cost ranges; that additional reserve information, as required under NI 51-101, will be included in our Annual Information Form which will be filed on SEDAR, EDGAR and our website in March ; and our expected RLIs, FDCs.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; the impact of Curtailment; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); that due to Curtailment and second half capital shift, that there will be follow-on affects to operating and general & administrative cost per boe; and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE" and "OBE.BC" respectively. All figures are in Canadian dollars unless otherwise stated.
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SOURCE Obsidian Energy Ltd.
CALGARY, Dec. 17, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces that its semi-annual borrowing base redetermination has resulted in a $30 million increase to its syndicated credit facility to $470 million. Additionally, Obsidian Energy provides an update on our latest Cardium drilling activity.
Increased Syndicated Credit Facility
The Company has a reserve-based syndicated credit facility, with an underlying borrowing base of $550 million, less the amount of outstanding pari passu senior notes. The increase in the syndicated credit facility from $440 million to $470 million is primarily due to the July 2018 retirement of an outstanding Pound Sterling cross currency swap.
The reserve-based syndicated credit facility is subject to a semi-annual borrowing base redetermination in May and November of each year.
Cardium Drilling Program Update
Obsidian Energy is pleased to report that our second half 2018 Cardium program is proceeding ahead of schedule and under budget. Additionally, well deliverability is meeting our updated type-curves as presented during our recent Investor Day. We now expect to have 10 wells on production prior to the end of 2018, up from five wells in our original plan.
To date, we have drilled 14 wells in Willesden Green, completing our second half 2018 program. Our technical team has optimized the design of one of our pads, resulting in one less well in the program while maintaining the same production rate expectations of approximately 2,700 bbl of oil per day and 3,800 boe per day in February 2019. Obsidian Energy will continue to bring our Willesden Green Cardium wells on production as planned, prioritizing our strongest netback production within the Alberta Government's mandated production curtailment.
Completions activity has progressed better than expected, with 10 wells fractured to date. Stimulation costs have been considerably under estimates resulting from optimized operations and service provider cost reductions. A summary of our strong production performance is outlined in the table below.
Pad | Status | Deliverability |
8-9 (3 wells) | On production | IP30 total pad: 1,762 boe per day (1,222 bbl of oil per day) IP30 per well: 587 boe per day (407 bbl of oil per day) |
14-1 (2 wells) | On production | IP20 total pad: 837 boe per day (697 bbl of oil per day) IP20 per well: 419 boe per day (348 bbl of oil per day) |
4-6 (3 wells) | On production mid-December | Initial flowback rates in line with pads above |
1-36 (2 wells) | On production end of December | Initial flowback rates in line with pads above |
9-2 (2 wells) | Early January completion | |
5-18 (2 wells) | Mid-January completion |
All figures contained in this release are in Canadian dollars.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our expectation for when certain wells to be on production and completed; production expectations despite their being one less well in the program; and that we will continue to bring our Willesden Green Cardium wells on production as planned, prioritizing our strongest netback production within the Alberta Government's mandated production curtailment.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; that the curtailment requirement will continue or improve as it stands today; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Nov. 15, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") announces its 2019 outlook. Obsidian Energy will be hosting its Investor Day Presentation later this morning to discuss the third quarter results disclosed last week, plans for 2019, the potential of our Cardium asset base and long-term strategy.
David French, President and CEO commented, "Consistent with our approach to the fourth quarter discussed last week, our 2019 plan is modest and built in reaction to recent moves across the crude oil complex. The goal is to live within our means and drive towards meaningful exit rate growth if prices allow. We will closely monitor the cash generation of our base production and forward development inventory. As such:
Assuming a base plan of $120 million of total capital, next year's program expects to deliver three to six percent absolute production growth year over year. Adding $40 million of capital to the second half of the year raises year over year production growth rates towards five to eight percent. The growth rates of both scenarios reflect our disciplined plan to reduce exposure to our negative cash flow legacy assets which we disclosed last week.
The backbone of our development plans will continue to be the Cardium, targeting ten percent production growth in that area. As is prudent, we will continue to closely monitor the business and have operational flexibility to match the macro environment. I look forward to speaking with the investment community later this morning to demonstrate the sound fundamentals of the underlying business, why we believe our assets are unique, and why 2019 holds promise for the Company."
2019 Outlook
Our 2019 plans are a disciplined approach to cash flow generation, balancing profitable growth initiatives with balance sheet preservation. Obsidian Energy is rapidly building the largest inventory of drill ready primary Cardium locations in the Company's history, which allows us to shift and increase capital as Canadian commodity price scenarios improve.
Our planned 2019 capital investment of $120 million includes $92 million of development capital associated with drilling, well licensing, lease preparation and existing wellbore optimization. Total Capital also includes $28 million of maintenance capital, corporate capital, operating cost reduction initiatives and decommissioning expenditures as part of the Alberta Energy Regulator's Area-Based Closure initiative.
Our development capital is approximately 80 percent weighted to the Cardium. Our plans include 15 horizontal producers (gross operated wells) in Willesden Green, with seven in the first half of the year. We also expect to spend $5 million on surface lease acquisitions and minor infrastructure projects. Included in the 2019 Cardium spend is the completion costs for five 2018 Willesden Green wells not fracture simulated by the end of this year.
The remaining 20 percent of our development capital will roughly spread evenly between optimization of existing wellbores, non-operated primary drilling activity and two (gross) Deep Basin wells. The projected capital efficiency of our 2019 development capital is approximately $15,000 per boe per day, based on the 12-month forward production associated with each project.
Capital Expenditure Details
Our 2019 Total Capital Expenditure guidance of $120 million is as follows:
Capital Category | # of Wells | Net Capital |
Cardium | 15 Producers | $71 million |
Deep Basin | 2 Producers | $7 million |
Non-Operated Primary Drilling | 2.5 net Producers | $6 million |
Existing Wellbore Optimization | >25 Projects | $8 million |
Total E&D Capital Expenditures | $92 million | |
Maintenance, Corporate & | $28 million | |
Total Capital Expenditures | $120 million |
Second half 2019 Capital has the flexibility to be increased by approximately $40 million of Cardium development (10 gross operated wells) if the outlook for crude oil pricing improves. The decision on Total Capital spend will be made by spring break-up.
Production and Cost Guidance
2019 Annual Guidance | |
FY 2019 Production | 28,000 to 29,000 boe per day |
FY 2019 Growth Rate (1) | 3% -6% |
Operating Costs | $13.00 - $13.50 per boe |
General & Administrative | $1.75 - $2.25 per boe |
(1) | Relative to projected full year 2018 production (using midpoint of guidance), adjusted for shut in volumes, of 27,250 boe per day |
Production growth rates would increase by approximately two percent if the Company elects to increase its Total Capital spend to $160 million and add approximately 1,000 boe per day of Cardium production in Q4 2019.
Investor Day Presentation Webcast Details
Obsidian Energy Management will be giving a presentation via webcast later this morning beginning at 9:00 am Mountain Time (11:00 am Eastern Time). This presentation will offer the investment community a comprehensive discussion about our third quarter results disclosed last week, plans for 2019, the potential of our Cardium asset base and long-term strategy. The event will be held in Calgary for analysts and sales representatives and simultaneously webcast for the broader investment community. A copy of the presentation will be available on the website after the presentation. To access the webcast please use the following URL:
https://event.on24.com/wcc/r/1850864/107BFCA7194ADB4B52B1FE66B4967F4E
Investors are invited to ask questions through the online webcast portal throughout the presentation. A recording will be available for replay following the conclusion of the presentation on our website www.obsidianenergy.com, or directly at above URL.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the Company will host its Investor Day and webcast later this morning to discuss third quarter results, plans for 2019, the potential for our Cardium asset base and long-term strategy and the presentation will be available on the website after the presentation; that we plan to live within our means and drive towards meaningful exit rate growth if prices allow; that we will closely monitor the cash generation of our base production and forward development inventory; that should pricing improve towards the second half of the year, the second half program can be increased by $40 million of capital spend thru adding two additional rigs to the Cardium program, which would bring our 2019 total capital spend to $160 million; our expectation for absolute production growth on a year over year basis based under both budget scenarios; that the backbone of our development plans will continue to be within the Cardium, targeting at least ten percent production growth in that area; that we will continue to closely monitor the business and have operational flexibility to match the macro environment; that our 2019 plans are a disciplined approach to cash flow generation, balancing profitable growth initiatives with balance sheet preservation; that we are rapidly building the largest drill ready primary Cardium locations in the Company's history which allows us to shift and increase capital as Canadian commodity price scenarios improve; what our planned capital investment includes under both budget scenarios; our projected capital efficiency of our 2019 development capital; our 2019 annual guidance for production, growth rate, operating and G&A cost ranges; and the impact to production growth rates if the total capital spend is increased to $160 million and adds approximately 1,000 boe per day of Cardium production in Q4 2019.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Oct. 10, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce an operational update and timing details for our third quarter results and Investor Day.
Operational Update
Obsidian Energy is on track to deliver meaningful 2019 light oil production growth from our Willesden Green Cardium program. The second half 2018 Cardium drilling program has been evaluated across a range of pricing and crude oil differentials. With the expected well rates and costs, Obsidian Energy anticipates competitive economic returns with the current outlook on Canadian dollar light oil differentials.
The first rig in Willesden Green finished drilling the three well 08-09 pad within the Crimson Lake unit. These wells will be completed in mid-October, with production expected to be online in mid-November. The wells are directly offsetting five wells from earlier this year which averaged 650 boe per day per well (85 percent oil) for the first 30 days of production. During drilling operations at 08-09, we noted very similar geological structure and quality, drilling rates, and strip log readings to the offset wells drilled from the five wells earlier this year. The second well on this pad is our new pacesetter for wells that require intermediate casing. We drilled this well in less than 13.4 days, approximately 20 percent faster than our H1 2018 program.
We now have two active rigs in the Cardium just east of the North Saskatchewan River in the Eastern flank of Willesden Green. The rigs are drilling directly offsetting a two well pad from earlier this year which averaged approximately 375 boe per day per well (87 percent oil) for both the first 30 and 60 days of production. The first rig has finished drilling the first well on our two well 14-01 pad, and completions for the pad will begin in late October. We drilled all 4,100 meters of main hole in this monobore well using a single bottom-hole assembly. The second rig has finished drilling its second well on the three well 04-06 pad. Fracturing operations will begin on this pad in mid-November.
Between the two rigs we have in the area, we are drilling the seventh and eighth wells of our 15 well second half program. We continue to expect five of the 15 wells to be producing by December 31, with the remaining 10 wells coming on production early in the first quarter of 2019.
Our single, second half 2018 Deep Basin well was rig released on July 28 and fracked in early-August. Drilling and completion costs came in on budget and strong production rates came online in late August. The well averaged 1,430 boe per day over the first 30 days of production, with liquids ratios better than expected at approximately 85 bbls/mmcf (approximately 490 bbl/d), of which 55 bbls/mmcf (approximately 325 bbl/d) is free condensate.
In Peace River, we are currently drilling the fourth well of our four well second half program. We have averaged 8 legs per well and reservoir characteristics look strong with good oil shows. Oil production from the first two well pad is expected to come online within the next week, and the next two well pad is scheduled to come online in mid-November. The Peace River joint industry gas gathering system and gas plant was on-stream in advance of the September 30, 2018 Alberta Energy Regulator Directive-84 regulatory deadline. Current plant throughput is approximately 3,500 mcf per day net to Obsidian Energy.
Third Quarter Results and 2019 Budget to be Announced November 8, 2018
Obsidian Energy is expected to release its third quarter 2018 financial and operating results and 2019 Budget on November 8, 2018 before markets open in North America. In addition, the third quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov in due course.
There will be no conference call accompanying the quarterly release as management will be giving a comprehensive presentation via webcast during Investor Day the following week.
Investor Day to be Held November 15, 2018
The presentation will begin at 9:00 am Mountain Time (11:00 am Eastern Time) and will offer the investment community a comprehensive technical overview of our current operations, long term development potential and corporate strategy. The event will be held in Calgary for analysts and sales representatives and simultaneously webcast for the broader investment community. Webcast details will be announced with our third quarter results expected to be disseminated on November 8, 2018.
Obsidian Energy shares are listed on both the Toronto Stock Exchange under the symbol "OBE" and the New York Stock Exchange under the symbol "OBE.BC".
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: taking into account the expected well rates and costs in the Willesden Green Cardium program, the anticipated competitive economic returns with the current outlook on Canadian dollar light oil differentials; that we will hold an Investor Day, the contents of that presentation and that there will be a webcast as well; the expected date for the dissemination of our third quarter results and 2019 Budget; that there will be no conference call with the third quarter results release; and the expected timing for completion and production of certain wells, pads and fracturing operations.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil | Natural Gas | ||
bbl | barrel or barrels | mcf | thousand cubic feet |
bbl/d | barrels per day | mmcf | million cubic feet |
boe/d | barrels of oil equivalent per day | mmcf/d | million cubic feet per day |
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-announces-operational-update-and-investor-day-details-300728409.html
SOURCE Obsidian Energy Ltd.
CALGARY, Sept. 18, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE - OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces that it received notification on September 18, 2018 from the New York Stock Exchange (the "NYSE") that Obsidian Energy is no longer in compliance with one of the NYSE's continued listing standards because the average closing price of Obsidian Energy's common shares was less than US$1.00 per share over a consecutive 30 trading day period. As of September 14, 2018, the average closing price of Obsidian Energy's common shares over the preceding consecutive 30 trading day period was US$0.99 per share. The issuance of the notification is not discretionary and is sent automatically when a listed company's share price falls below the NYSE's minimum price listing standard.
Under the NYSE's rules, Obsidian Energy can avoid delisting if, within six months from the date of the NYSE notification, its common shares have a closing price on the last trading day of any calendar month and a concurrent 30 trading day average closing price of at least US$1.00 per share. If at the expiration of the applicable cure period Obsidian Energy has not regained compliance, the NYSE will commence suspension and delisting procedures. We believe that the continued execution of the Company's business plan will lead to an increase in the share price over time and thereby bring Obsidian Energy into compliance with the Minimum Share Price Listing Standard.
Non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the U.S. Securities and Exchange Commission (the "SEC"), nor does it affect the continued listing and trading of Obsidian Energy's common shares on the Toronto Stock Exchange (the "TSX"). Obsidian Energy intends to notify the NYSE within 10 business days from the date of the notification that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period.
Obsidian Energy's common shares will continue to be listed and traded on the NYSE during the applicable cure period, subject to compliance with the NYSE's other continued listing standards, under the symbol "OBE", but the NYSE will assign a ".BC" indicator to the symbol to denote that Obsidian Energy is below the NYSE's price listing standard. This indicator will be removed at such time as Obsidian Energy is deemed compliant with the NYSE's price listing standard.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, that non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the SEC, our belief that the continued execution of the Company's business plan will lead to an increase in the share price over time and thereby bring Obsidian Energy into compliance with the Minimum Share Price Listing Standard; Obsidian Energy's ability to regain compliance with the NYSE's price listing standard within the applicable cure period; that if at the expiration of the applicable cure period Obsidian Energy has not regained compliance, the NYSE will commence suspension and delisting procedures; Obsidian Energy's intention to notify the NYSE within 10 business days that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period; and the continued listing and trading of Obsidian Energy's common shares on the TSX.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward‑looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 2, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the three and six months ended June 30, 2018. All figures are in Canadian dollars unless otherwise stated.
David French, President and CEO commented, "The second quarter of 2018 was a relatively quiet one for development, as we took advantage of seasonal breakup to prepare for our second half drilling program. Obsidian Energy's team safely completed a major turnaround at our Company's biggest facility in Willesden Green on time and on budget, monitored the non-operated gas processing facility construction in Peace River while advancing our own gathering system in the area, and kicked off lease construction for our summer drilling program.
Our corporate cash flow continues to be constrained by our hedging program in 2018. The combination of wide differentials and a fulsome hedge book hamper our corporate netback right now, but the significant cash generating potential of our field operations remains. That all translates to funds flow from operations in the quarter of $32 million, which is slightly down from the first quarter. Additional maintenance activity was reflected in the opex per boe results of $14.47 per boe, but costs will trend down in second half of the year.
The next several months will be instrumental for the Company. In the second quarter, our Board approved an incremental $50 million of capital earmarked for primary Cardium development. The increased budget sets the stage for growth as we embark on focused Willesden Green development and look to add meaningful light oil volumes into 2019. This production build will position Obsidian Energy to capitalize on strong commodity prices as we roll out of our 2018 hedge book, and see a meaningful uptick in cash flow from organic growth.
We believe the investment community is beginning to recognize that the stage is set for our underlying business to perform very well. We look forward to previewing our preliminary 2019 plans and long term inventory potential at our fall Investor Day and providing an update on our drilling activities with third quarter results."
Financial and Operating Highlights
Three months ended June 30 |
Six months ended June 30 | ||||||||||
2018 |
2017 |
% change |
2018 |
2017 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Funds flow from operations (1) |
$ |
32 |
$ |
43 |
(26) |
$ |
67 |
$ |
100 |
(33) | |
Basic per share (1) |
0.06 |
0.09 |
(33) |
0.13 |
0.20 |
(35) | |||||
Diluted per share (1) |
0.06 |
0.09 |
(33) |
0.13 |
0.20 |
(35) | |||||
Net income (loss) |
(96) |
(9) |
>100 |
(161) |
18 |
>(100) | |||||
Basic per share |
(0.19) |
(0.02) |
>100 |
(0.32) |
(0.04) |
>100 | |||||
Diluted per share |
(0.19) |
(0.02) |
>100 |
(0.32) |
(0.04) |
>100 | |||||
Capital expenditures (2) |
26 |
24 |
8 |
86 |
50 |
72 | |||||
Net Debt (1) |
$ |
408 |
$ |
387 |
5 |
$ |
408 |
$ |
387 |
5 | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
13,379 |
13,396 |
- |
13,892 |
14,966 |
(7) | |||||
Heavy oil (bbls/d) |
5,172 |
5,636 |
(8) |
4,963 |
5,423 |
(8) | |||||
Natural gas (mmcf/d) |
61 |
68 |
(10) |
61 |
75 |
(18) | |||||
Total production (boe/d) (3) |
28,697 |
30,436 |
(6) |
29,068 |
32,655 |
(11) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
72.32 |
$ |
56.12 |
29 |
$ |
68.16 |
$ |
55.94 |
22 | |
Heavy oil (per bbl) |
46.81 |
31.61 |
48 |
39.45 |
32.37 |
22 | |||||
Natural gas (per mcf) |
$ |
1.62 |
$ |
3.10 |
(48) |
$ |
2.24 |
$ |
3.16 |
(29) | |
Netback per boe (3) |
|||||||||||
Sales price |
$ |
45.59 |
$ |
37.51 |
22 |
$ |
44.04 |
$ |
38.11 |
16 | |
Risk management gain (loss) |
(7.28) |
2.21 |
>(100) |
(5.73) |
2.91 |
>(100) | |||||
Net sales price |
38.31 |
39.72 |
(4) |
38.31 |
41.02 |
(7) | |||||
Royalties |
(4.09) |
(2.67) |
53 |
(3.40) |
(2.68) |
27 | |||||
Operating expenses (4) |
(14.47) |
(16.44) |
(12) |
(14.66) |
(16.07) |
(9) | |||||
Transportation |
(3.24) |
(2.82) |
15 |
(3.20) |
(2.55) |
25 | |||||
Netback (1) |
$ |
16.51 |
$ |
17.79 |
(7) |
$ |
17.05 |
$ |
19.72 |
(14) |
(1) |
The terms "funds flow from operations" and their applicable per share amounts, "Net Debt", and "netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(2) |
Includes the effect of capital carried from its partner under PROP in 2017. The benefit of carried capital expenditures from the Company's partner under the Peace River Oil Partnership ("PROP") was fully utilized in December 2017. |
(3) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(4) |
Operating costs per boe is presented excluding the impact of carried operating expenses. The benefit of carried operating expenses from the Company's partner under PROP was fully utilized in December 2017 |
The table below outlines select metrics in our key development and legacy areas for the three months ended June 30, 2018 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended June 30, 2018 | |||
Production |
Liquids |
Operating |
Netback | |
Cardium(1) |
18,400 boe/d |
66% |
$17/boe |
$27/boe |
Deep Basin |
1,541 boe/d |
24% |
$1/boe |
$18/boe |
Alberta Viking |
1,782 boe/d |
51% |
$10/boe |
$25/boe |
Peace River |
4,834 boe/d |
99% |
$11/boe |
$24/boe |
Key Development Areas |
26,557 boe/d |
68% |
$14/boe |
$26/boe |
Legacy Areas |
2,140 boe/d |
20% |
$17/boe |
$(4)/boe |
Key Development & Legacy Areas |
28,697 boe/d |
65% |
$14/boe |
$24/boe |
(1) |
Includes the impact of turnaround activities in the second quarter |
The table below provides a summary of our operated activity in the second quarter.
Number of Wells Q2 2018 | ||||||||
Drilled |
Completed |
On-stream | ||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||
Cardium |
||||||||
Producer |
0 |
0.0 |
2 |
1.4 |
3 |
1.9 | ||
Injector |
0 |
0.0 |
3 |
3.0 |
6 |
6.0 | ||
Deep Basin |
0 |
0.0 |
0 |
0.0 |
0 |
0.0 | ||
Alberta Viking |
0 |
0.0 |
0 |
0.0 |
0 |
0.0 | ||
Peace River |
1 |
0.6 |
1 |
0.6 |
1 |
0.6 | ||
Total |
1 |
0.6 |
6 |
5.0 |
10 |
8.4 |
Operational Update
Our Willesden Green well brought on-stream in April is currently producing approximately 300 boe per day, with rates of 780 boe per day for the first 30 days of production and 580 boe per day for the first 60 days of production (60 percent liquids). The first three wells in our second half 2018 program are directly offsetting this well, and drilling commenced on July 30.
In Pembina, two wells in PCU#11 came on-stream in April. With rates of 200 boe per day per well (gross) for the first 30 days of production, these wells are meeting expectations. Our four well pad in PCU#9 came on production with expected total fluid rates but with higher water cuts. Pad production for July is behind expectations at approximately 375 boe per day, and infrastructure optimization work is ongoing to debottleneck the area. We are confident in the significant running room throughout our Pembina acreage and look forward to presenting the long term inventory potential of the assets.
While wet weather slowed the post breakup start in Willesden Green by a few days, we are currently running one rig in the area. We drilled our sole Mannville well on route south to our Cardium program, which was rig released on July 28 and will be fracked in early-August. We also participated in a non-operated Mannville well which is expected to come online in the third quarter.
Our second half 2018 Willesden Green program is comprised of 15 horizontal drills off six multi-well pads. The average lateral length is approximately 1.5 miles per well, and all are within close proximity of our successful first half program. The first rig will drill a three well pad on the west side of the North Saskatchewan River in early August, moving to the eastern flank of the play later in the year. A second rig will begin drilling on the east side of the river in mid-September, and we plan to run both rigs until the 2019 break-up season. We plan to have 5 wells on production by the end of December, with the remaining wells coming on production early 2019. We have also kicked off surface acquisition and licensing process for a material 2019 program and are well positioned for a consistent pace of development throughout the year and beyond. We will provide additional detail on our drilling plans, inventory and expected growth wedge with our fall Investor Day.
In Peace River, our first half program continues to exceed expectations. The four wells had average peak rates above 500 bbl per day, and production over the first 90 days has averaged 400 bbl per day per well (gross). As a result of this performance and the economics of future wells in the current commodity price environment, we have elected to re-allocate capital from our scheduled Alberta Viking program to four additional Peace River wells. The wells will be drilled for approximately the same capital cost net to Obsidian Energy and are expected to come on production in the fourth quarter.
The Peace River joint industry gas gathering system and gas plant is proceeding on schedule, and we expect to have the system on-stream well in advance of the September 30, 2018 AER Directive-84 regulatory deadline. Commissioning of the non-operated plant started in late July and all Peace River solution gas will be online and delivering to the plant by mid-September. Spending increased by approximately $5 million, due to construction cost overruns as plans were finalized for the gathering system and plant.
Current Hedging Position
No hedges were added recently as we are already at approved levels for the next 12 months. With the business freeing up from one-time costs in 2018 and potential dispositions impacting both debt and production levels next year, we do not expect to add incremental 2019 hedges at this time. Currently, the Company has the following crude oil hedges in place:
Q3 2018 |
Q4 2018 |
Q1 2019 |
Q2 2019 |
Q3 2019 | ||
WTI $USD |
$50.05 |
$49.78 |
$50.02 |
$56.53 |
$57.00 | |
bbl/day |
8,000 |
8,000 |
3,000 |
2,000 |
1,000 | |
WTI $CAD |
$71.04 |
$71.04 |
$67.88 |
$68.58 |
- | |
bbl/day |
4,000 |
4,000 |
6,000 |
4,000 |
- | |
Total |
||||||
bbl/day |
12,000 |
12,000 |
9,000 |
6,000 |
1,000 |
Additionally, the Company has the following foreign exchange contracts in place:
Currently, the Company has the following natural gas hedges in place:
Q3 2018 |
Q4 2018 | ||
AECO $CAD |
$2.67 |
$2.67 | |
mcf/day |
17,100 |
15,200 | |
Ventura $USD (1) |
$2.79 |
$2.79 | |
mcf/day |
7,500 |
7,500 | |
Total |
|||
mcf/day |
24,600 |
22,700 |
(1) |
Through the third quarter of 2020, the Company has an agreement in place to sell 15 mmcf per day of natural gas at the Ventura index price less the cost of transportation from AECO. Recent transportation deductions for the Company to bring product to the Ventura market have been approximately $0.55 per mcf. |
Management Changes
The Company is pleased to announce that Mr. Aaron Smith has joined the Company as Vice President, Development.
Mr. Smith has over 20 years of engineering expertise across a broad range of technical and leadership roles. Most recently, Mr. Smith held the position of Vice President, Production at a diversified oil and natural gas company based in Calgary. Prior to that, Mr. Smith held various management positions overseeing major development campaigns in Western Canada, successfully executing horizontal drilling programs targeting liquids rich formations such as the Cardium. Mr. Smith's technical expertise and leadership capabilities will prove critical as the Company fast tracks Cardium development with a repeatable, low cost approach.
The Company also announces two additional management changes. Mr. Mark Hodgson has transitioned to the role of Vice President, Operations and E&P Services, and Mr. Andrew Sweerts has assumed the role of Vice President, Business Development and Commercial.
Full Year 2018 Guidance
Our Total Capital Expenditure Guidance reflects the Peace River and Alberta Viking drilling and regulatory spend updates noted above:
Capital Category |
# of Operated Wells |
Net Capital |
Cardium |
24 Producers |
$101 million |
Deep Basin |
2 Producers |
$7 million |
Peace River |
8 Producers |
$14 million |
Alberta Viking |
0 Producers |
$0 million |
Existing Wellbore Optimization |
>50 Projects |
$14 million |
Total Development |
34 Producers |
$136 million |
Regulatory Directive 84 Requirements |
$19 million | |
Infrastructure & Corporate Capital |
$25 million | |
Total E&D Capital Expenditures |
$180 million | |
Decommissioning Expenditures |
$10 million | |
Total Capital Expenditures |
$190 million |
2018 production and operating cost guidance is unchanged:
2018 Annual Guidance | |
Production |
29,000 to 30,000 boe per day |
Production Growth Rate (1) |
5% |
Operating Costs |
$13.00 - $13.50 per boe |
General & Administrative |
$2.00 - $2.50 per boe |
(1) |
Relative to full year 2017 production, adjusted for all 2017 & 2018 A&D, of 28,000 boe per day |
Fall 2018 Investor Day
The Company will be webcasting an Investor Day presentation later this fall. The presentation will offer the investment community a technical asset overview and preliminary corporate guidance for 2019. Webcast details will be disseminated at a later date.
Second Quarter 2018 Financial Results Conference Call Details
A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) on August 2, 2018.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1791004/DC2D21D21A48076B2901BDEE400E9328
A digital recording will be available for replay two hours after the call's completion, and will remain available until August 16, 2018, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 6083229, followed by the pound (#) key.
An updated corporate presentation has been added to Obsidian Energy's website at www.obsidianenergy.com.
Confirms Filing of Year-End Disclosure Documents
On March 7, 2018, Obsidian Energy filed its audited Consolidated Financial Statements for the year ended December 31, 2017 and related Management's Discussion and Analysis with Canadian securities regulatory authorities. Obsidian Energy has also filed its Annual Information Form for the year ended December 31, 2017, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101 on that date. Obsidian Energy's Annual Report on Form 40-F for the year ended December 31, 2017 was filed on March 8, 2018, with the U.S. Securities and Exchange Commission pursuant to its rules and regulations at that time.
Copies of these documents may be obtained electronically via www.sedar.com and www.sec.gov/edgar.shtml (for the Form 40-F) or through Obsidian Energy's website at www.obsidianenergy.com. Hard copies of Obsidian Energy's audited Consolidated Financial Statements and related MD&A are also available upon request, free of charge, by contacting our Investor Relations group or by requesting them through our website.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil |
Natural Gas | ||
bbl |
barrel or barrels |
Mcf |
thousand cubic feet |
bbl/d |
barrels per day |
MMcf |
million cubic feet |
Mbbl |
thousand barrels |
Bcf |
billion cubic feet |
MMbbl |
million barrels |
Mcf/d |
thousand cubic feet per day |
boe/d |
barrels of oil equivalent per day |
MMcf/d |
million cubic feet per day |
Non-GAAP Measures
Certain financial measures including Funds Flow from Operations, Funds Flow from Operations per share-basic, Funds Flow from Operations per share-diluted, netback and net debt included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds Flow from Operations is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of Funds Flow from Operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's netbacks. Net debt includes long-term debt and includes the effects of working capital and all cash held on hand.
Calculation of Funds Flow from Operations
(millions, except per share amounts) |
Three months ended June 30 |
Six months ended June 30 | |||||||
2018 |
2017 |
2018 |
2017 | ||||||
Cash flow from operating activities |
$ |
(20) |
$ |
19 |
$ |
37 |
$ |
57 | |
Change in non-cash working capital |
26 |
14 |
(6) |
16 | |||||
Decommissioning expenditures |
1 |
3 |
3 |
7 | |||||
Office lease settlements |
4 |
4 |
9 |
8 | |||||
Settlements of normal course foreign exchange contracts |
- |
(8) |
- |
(8) | |||||
Realized foreign exchange loss – debt maturities |
8 |
1 |
8 |
4 | |||||
Carried operating expenses (1) |
- |
6 |
- |
10 | |||||
Restructuring charges – cash portion |
7 |
4 |
8 |
6 | |||||
Other expenses |
6 |
- |
8 |
- | |||||
Funds flow from operations |
$ |
32 |
$ |
43 |
$ |
67 |
$ |
100 | |
Per share |
|||||||||
Basic per share |
$ |
0.06 |
$ |
0.09 |
$ |
0.13 |
$ |
0.20 | |
Diluted per share |
$ |
0.06 |
$ |
0.09 |
$ |
0.13 |
$ |
0.20 |
(1) The benefit of carried operating expenses from the Company's partner under PROP was fully utilized in December 2017. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: the opex costs will trend down in the second half of the year; that the increased budget will lead to development and meaningful light oil volumes into 2019, and the production growth will position the Company to capitalize on strong commodity prices as we roll out of our 2018 hedge book, and see a meaningful uptick in cash flow from organic growth; that we will conduct an investor day in the fall and provide an update on activities at that time and that it will be webcasted; that the Company will settle the long-term office lease claim with the payments and timing set forth and that it will settle the outstanding claim; that we continue to have discussions with CIC regarding a sale of the Peace River asset towards the end of the year; that we remain committed to reducing debt, accelerating growth and buying back shares with any meaningful asset sale proceeds; that the investment community is beginning to recognize that the stage is set for our underlying business to perform very well; that the rail contracts maintains our marketing flexibility in the area going forward; our fracking expectations for the future in the Mannville; that there is significant running room throughout Pembina; our drilling schedule and location expectations; our expectations for drilling costs and production timing for certain wells; that we expect to have the joint industry gas gathering system on-stream well in advance of the AER Directive-84 regulatory deadline; that we do not expect to add incremental 2019 hedges at this time.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-announces-second-quarter-2018-financial-and-operational-results-300690791.html
SOURCE Obsidian Energy Ltd.
CALGARY, June 4, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce an additional $50 million of 2018 Cardium development capital, following up on our recent success in the Willesden Green play fairway.
David French, President and CEO commented, "We are entering a new stage of development by fast tracking our Cardium drilling in Willesden Green. Our recent results, material acreage position, and low base decline rate enable us to step up growth and provide torque to rising 2019 commodity prices. The short cycle inventory we see in our units and the halo of the play demand more investment. We will spend an incremental $50 million in the remainder of 2018, with the majority of production and cash flow coming on near year end."
Adding $50 million of Willesden Green capital to drill 13 primary wells
The development capital increase includes 13 wells in the eastern part of Willesden Green, both inside the unit and along the halo flank of the area. All 13 wells are informed by offset producing wells that have exceeded internal expectations. Included in the $50 million is $4 million of infrastructure capital which sets up future development opportunities along the eastern side of the play. The capital will be spent throughout the third and fourth quarter, with production beginning to come on line late this year.
The incremental wells will be brought on production with an estimated 12-month capital efficiency of $20,000 per boe per day, averaging over 80 percent rate of return at strip prices. We expect to add approximately 2,300 boe per day in full year 2019 from these wells, with monthly production hitting approximately 3,500 boe per day early in the year. We have multiple years of inventory, with line of sight to 80 Willesden Green primary locations and additional primary development potential currently being evaluated.
After initial one-time investment in related infrastructure, we believe we can lower capital efficiencies under $20,000 per boe per day in 2019 and continue to drive significant light oil production growth. We will provide further details on our developments plans and significant running room in the play this fall.
Program backstopped by our balance sheet; accretive to year-end 2019 leverage
We will fund this additional development primarily through our existing credit facility, supplemented with minor dispositions of underutilized and undeveloped acreage. As of May 31, approximately $310 million was drawn on our $440 million credit facility, providing us with sufficient liquidity to execute on this program. The amount drawn includes the recent payment of a US$24 million Senior Note maturity. Despite the increase in capital and backwardation in the crude forward curve, we expect year-end 2019 leverage metrics to approach 1.5 times Senior Debt to EBITDA as a result of the incremental production and cash flow from our development program.
Asset sales update
Since early May, we have entered into several transactions for existing third-party royalty interests totaling approximately $7.5 million in proceeds. Transaction metrics averaged over 20 times and $200,000 per boe per day based on trailing 12-month cash flow and production, respectively. We will continue to progress small additional deals for existing royalties and undeveloped acreage in the coming months.
We have chosen not to sell our Alberta Viking position at this time, as offers were below our view of intrinsic value given: the strong returns at strip pricing, depth of inventory, infrastructure processing advantage and the ability to fund our enhanced Cardium program via a different alternative.
We continue to have ongoing dialogue with China Investment Corporation regarding a potential sale of the Company's Peace River assets towards the end of the year. We remain committed to reducing debt, accelerating growth and buying back shares with any meaningful asset sale proceeds.
Guidance Update
Our updated Total Capital Expenditure Guidance is as follows:
Capital Category |
# of Operated Wells |
Net Capital |
Cardium |
24 Producers |
$101 million |
Deep Basin |
2 Producers |
$7 million |
Peace River |
4 Producers |
$8 million |
Alberta Viking |
4 Producers |
$6 million |
Existing Wellbore Optimization |
>50 Projects |
$14 million |
Total Development |
34 Producers |
$136 million |
Regulatory Directive 84 Requirements |
$14 million | |
Infrastructure & Corporate Capital |
$25 million | |
Total E&D Capital Expenditures |
$175 million | |
Decommissioning Expenditures |
$10 million | |
Total Capital Expenditures |
$185 million |
As a result of the additional Cardium wells not expected to come on stream until late in the year, we will update full year 2018 guidance as part of our normal second quarter release when final drilling and development plans are in place.
2018 Annual Guidance | |
Production |
29,000 to 30,000 boe per day |
Production Growth Rate (1) |
5% |
Operating Costs |
$13.00 - $13.50 per boe |
General & Administrative |
$2.00 - $2.50 per boe |
(1) |
Relative to full year 2017 production, adjusted for all 2017 & 2018 A&D, of 28,000 boe per day |
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
The term EBITDA included in this release does not have a standardized meaning prescribed by IFRS and therefore is considered a non-GAAP measure; accordingly, it may not be comparable to similar measures provided by other issuers. EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. In addition, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation. EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated bank facility and senior notes.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we are entering a new stage of development by fast tracking our Cardium drilling in Willesden Green; that our recent results, material acreage position, and low base decline rate enable us to step up growth and provide torque to rising 2019 commodity prices; that we will spend an incremental $50 million in the remainder of 2018, with a majority of production and cash flow coming on near year end; the number and location of the additional wells with the development capital increase; that included in the $50 million is $4 million of infrastructure capital which sets up future development opportunities along the eastern side of the Willesden Green play; the expected timing of the capital spend and when production will come on line and its impact to 2018 production numbers; the expected 12-month capital efficiency of the incremental wells to be brought on production and average rate of return at strip prices; expected production increases from these incremental wells in 2019; that we have multiple years of inventory, with line of sigh to 80 Willesden Green primary locations and additional primary development potential currently being evaluated; the believe that we can lower capital efficiencies in 2019 and continue to drive significant light oil production growth; that we will provide an update on the play in the fall; how we will fund this additional development; the expectation for year-end 2019 leverage metrics as a result of the incremental production and cash flow from our development program; that we will continue to progress small additional deals for existing royalties and undeveloped acreage in the coming months; the potential sale of the Company's Peace River assets towards the end of the year; that we remain committed to reducing debt, accelerating growth and buying back shares with any meaningful asset sale proceeds; the 2018 annual guidance for production, production growth rate, operating costs and general and administrative costs; that we will update full year 2018 guidance as part of our normal second quarter release when final drilling and development plans are in place.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things, that we do not dispose of any material producing properties other than stated herein; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
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SOURCE Obsidian Energy Ltd.
CALGARY, May 11, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that at its annual and special meeting of shareholders held on May 11, 2018, Obsidian Energy's shareholders approved all resolutions outlined in the Notice of 2018 Annual and Special Meeting and Management Proxy Circular dated April 6, 2018 (the "Information Circular"), which is available on SEDAR at www.sedar.com, on EDGAR at www.sec.gov, and on Obsidian Energy's website at www.obsidianenergy.com.
1. Appointment of Auditor
By resolution passed by show of hands, Ernst & Young LLP, Chartered Accountants, was appointed as auditor of Obsidian Energy for the ensuing year.
2. Election of Directors
By resolutions passed by ballot vote, the following ten nominees proposed by management were elected as directors of the Company to hold office until the next annual meeting of Shareholders or until their successors are elected or appointed:
Name of Nominee |
Votes For |
Percent |
Votes Withheld |
Percent |
John Brydson |
208,268,944 |
94.18% |
12,860,588 |
5.82% |
Raymond D. Crossley |
173,540,960 |
78.48% |
47,588,572 |
21.52% |
Michael J. Faust |
212,121,534 |
95.93% |
9,007,998 |
4.07% |
David L. French |
173,797,525 |
78.60% |
47,332,007 |
21.40% |
William A. Friley |
173,503,281 |
78.46% |
47,626,251 |
21.54% |
Maureen Cormier Jackson |
172,937,537 |
78.21% |
48,191,995 |
21.79% |
Edward H. Kernaghan |
182,654,664 |
82.60% |
38,474,868 |
17.40% |
Stephen Loukas |
212,872,911 |
96.27% |
8,256,621 |
3.73% |
Gordon Ritchie |
205,028,443 |
92.72% |
16,101,089 |
7.28% |
Jay W. Thornton |
190,613,504 |
86.20% |
30,516,028 |
13.80% |
3. Non-Binding Advisory Vote on the Corporation's Approach to Executive Compensation
By resolution passed by ballot vote, an advisory resolution was passed to approve the Company's approach to executive compensation as outlined in the Information Circular. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
174,340,867 |
78.84% |
46,786,538 |
21.16% |
Obsidian Energy shares are listed on the Toronto Stock Exchange and the New York Stock Exchange under the symbol "OBE".
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SOURCE Obsidian Energy Ltd.
CALGARY, May 11, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the three months ended March 31, 2018. All figures are in Canadian dollars unless otherwise stated.
David French, President and CEO commented, "Obsidian Energy had another solid quarter of drilling success, especially with momentum building in Willesden Green where our results continue to exceed expectations. Recent results and the short cycle inventory we see in the units and along the halo of the play demand more investment. The vast majority of future development capital will flow to Willesden Green primary drilling and will be the key growth driver over the quarters and years to come. Our Harmon Valley South program in Peace River yielded excellent results, partially offsetting lower than expected gas rates from our last Mannville test and frac delays in Pembina.
The Company's first quarter production and operating cost results were hampered by cold weather downtime, third party maintenance and operational delays. Relative to last quarter, our financials were challenged due to hedging losses and wide differentials. The impact of our hedging program does not represent our long term ability to generate cash flow, nor does it represent the underlying quality of our operations. With the business freeing up from one-time costs in 2018 and potential dispositions impacting both debt and production levels next year, we do not expect to add incremental 2019 hedges at this time.
Despite the temporary production and cash flow impacts in the quarter, we continue to expect full year production and operating costs within guidance ranges. Production levels increased in April with recent success within our optimization budget and new wells coming on-stream and cleaning up through the month. We are well positioned for a strong second half with corporate volumes averaging over 30,000 boe per day the last two weeks, and are ready to expand our capital program in Willesden Green pending results from our business development activities."
Challenges in the first quarter, but strong underlying operations reinforce full year guidance
First quarter production averaged 29,443 boe per day, a decrease of six percent relative to fourth quarter 2017. Our previously disclosed sale of legacy assets, cold weather related downtime, third party maintenance and lower than expected Mannville gas rates resulted in lower production volumes for the quarter. This was mitigated by strong underlying base operations, specifically development within our Willesden Green Cardium acreage. Corporate production volumes have been over 30,000 boe per day for the last two weeks.
First quarter operating costs were $14.86 per boe, a six percent decrease relative to the first quarter of 2017 and a three percent increase relative to fourth quarter 2017. Operating costs were impacted by cold weather, higher power costs and one-off spill related expenses.
Willesden Green rates meaningfully exceeding type curve, approximately $50 million in Cardium drill ready inventory on standby
Six Willesden Green Cardium wells were brought on production in the quarter and are some of industry's best wells drilled to date in the area. Our four well pad brought on in January averaged over 400 boe per day per well over the first 90 days of production, and our two well pad in the halo drilling window has averaged approximately 375 boe per day per well over its first 60 days of production. In addition, we demonstrated the readiness of our Willesden Green program and delivered an incremental well on budget and ahead of schedule. This well came on at the end of April flowing over 900 boe per day per well (72 percent liquids) while choked, over the first 15 days of production. Five of these new wells will receive pressure support from new injectors also drilled in Q1. We are excited by results seen to date in the halo acreage and the significant running room we have in this play.
Top decile results for the Peace River Oil Partnership
Three of our four Peace River Oil Partnership ("PROP") wells came on line in the first quarter, with average peak rates above 500 bbl per day per well, and 90-day initial production rates forecasted to be in the best 10 percent of wells drilled across our acreage. The fourth well came on production in late April and has already reached first oil, producing over 500 bbl per day in early May. These production rates coupled with recent uptick in crude oil pricing drives strong rates of returns on these wells.
Optimization program partially delayed due to weather, with debottlenecking projects and multi-zone tests now yielding highly capital efficient results
Our optimization budget has yielded highly capital efficient results as work accelerated at the end of the first quarter. We have added new production from existing wellbores at a 90-day initial production capital efficiency of approximately $8,000 per boe per day. We brought 23 projects on line in the first quarter on approximately $5 million of capital spend, with an additional $1 million spent on projects benefitting second quarter production. We continue to see success targeting the Blue Ridge, Nisku, and Bakken formations by stimulating and reactivating existing wellbores.
Improved pricing outlook and ongoing business development initiatives set up exciting second half of the year and beyond
We see meaningful cash flow improvement in 2019 as the business rolls beyond the 2018 hedge book, regulatory capital requirements in Peace River and the third quarter Pound Sterling hedge commitment. The unshackling of our business in 2019 will provide a marked increase in capital allocated for development, focused in Willesden Green. Our operational teams are ready to execute on a robust inventory of projects to further capitalize our considerable land base.
Financial and Operating Highlights
Three months ended March 31 | |||||||||
2018 |
2017 |
% change | |||||||
Financial |
|||||||||
Funds flow from operations (1) |
$ |
35 |
$ |
57 |
(39) | ||||
Basic and Diluted per share (1) |
0.07 |
0.11 |
(36) | ||||||
Net income (loss) |
(65) |
27 |
>(100) | ||||||
Basic and Diluted per share |
(0.13) |
0.05 |
>(100) | ||||||
Capital expenditures (2) |
60 |
26 |
>100 | ||||||
Net Debt |
$ |
407 |
$ |
405 |
- | ||||
Operations |
|||||||||
Daily production |
|||||||||
Light oil and NGL (bbls/d) |
14,412 |
15,962 |
(10) | ||||||
Heavy oil (bbls/d) |
4,751 |
5,206 |
(9) | ||||||
Natural gas (mmcf/d) |
62 |
82 |
(24) | ||||||
Total production (boe/d) (3) |
29,443 |
34,900 |
(16) | ||||||
Average sales price |
|||||||||
Light oil and NGL (per bbl) |
$ |
64.25 |
$ |
57.00 |
13 | ||||
Heavy oil (per bbl) |
31.34 |
33.21 |
(6) | ||||||
Natural gas (per mcf) |
$ |
2.87 |
$ |
3.22 |
(11) | ||||
Netback per boe (3) |
|||||||||
Sales price |
$ |
42.52 |
$ |
38.63 |
10 | ||||
Risk management gain (loss) |
(4.20) |
3.52 |
>(100) | ||||||
Net sales price |
38.32 |
42.15 |
(9) | ||||||
Royalties |
(2.73) |
(2.68) |
2 | ||||||
Operating expenses (4) |
(14.86) |
(15.78) |
(6) | ||||||
Transportation |
(3.16) |
(2.31) |
37 | ||||||
Netback (1) |
$ |
17.57 |
$ |
21.38 |
(18) |
(1) |
The terms "funds flow from operations" and their applicable per share amounts, and "netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(2) |
Includes the effect of capital carried from its partner under PROP in 2017. The benefit of carried capital expenditures from the Company's partner under PROP was fully utilized in December 2017. |
(3) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(4) |
Operating costs per boe is presented excluding the impact of carried operating expenses. The benefit of carried operating expenses from the Company's partner under PROP was fully utilized in December 2017. |
The table below outlines select metrics in our key development and legacy areas for the three months ended March 31, 2018 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended March 31, 2018 | |||
Production |
Liquids |
Operating |
Netback | |
Cardium |
19,081 boe/d |
66% |
$14/boe |
$28/boe |
Deep Basin |
1,292 boe/d |
22% |
$1/boe |
$22/boe |
Alberta Viking |
1,916 boe/d |
54% |
$11/boe |
$28/boe |
Peace River |
4,963 boe/d |
99% |
$12/boe |
$12/boe |
Key Development Areas |
27,252 boe/d |
69% |
$13/boe |
$25/boe |
Legacy Areas(1) |
2,191 boe/d |
25% |
$38/boe |
$(19)/boe |
Key Development & Legacy Areas |
29,443 boe/d |
65% |
$15/boe |
$22/boe |
(1) |
A portion of Legacy Areas includes assets sold in the first quarter. Refer to January 31, 2018 press release for more details. |
The table below provides a summary of our operated activity in the first quarter.
Number of Wells Q1 2018 | ||||||||
Drilled |
Completed |
On-stream | ||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||
Cardium |
||||||||
Producer |
6 |
4.7 |
7 |
6.0 |
6 |
5.6 | ||
Injector |
6 |
6.0 |
3 |
3.0 |
0 |
0.0 | ||
Deep Basin |
1 |
1.0 |
1 |
1.0 |
1 |
1.0 | ||
Alberta Viking |
0 |
0.0 |
0 |
0.0 |
0 |
0.0 | ||
Peace River |
3 |
1.7 |
3 |
1.7 |
3 |
1.7 | ||
Total |
16 |
13.3 |
14 |
11.7 |
10 |
8.3 |
Operational Update
Extreme cold weather in Western Canada impacted the first quarter results; we dealt with frozen casing, pumping equipment and pipelines. In total, we estimate cold weather impacted the quarter by approximately 500 boe per day. Production has now been fully restored and we are back to normal operations with average production over 30,000 boe per day over the last two weeks. Scheduled turnaround activity is expected to impact the second quarter by approximately 900 boe per day.
Our four well pad in Willesden Green Cardium came on-stream in January averaging nearly 650 boe per day per well (87 percent liquids) for the first 30 days of production, and over 400 boe per day per well for the first 90 days of production. We expect injection support to mitigate decline rates and meaningfully enhance the ultimate recovery from the wells. Our two well pad just east of this pad was brought on-stream in February and averaged 375 boe per day per well (87 percent liquids) for both the first 30 and 60 days of production.
As outlined in our year-end results press release, we elected to add an additional Willesden Green well to our program. This well came on at the end of April and was flowing over 900 boe per day per well (72 percent liquids) while choked, over the first 15 days of production. We will drill two more wells in the third quarter within close proximity to this well and have an additional 15 wells ready to execute should additional capital become available through our business development activities.
In Pembina, we have drilled and completed all six of our planned wells, which are accompanied by low cost injector conversions for waterflood support. Infrastructure constraints and weather delays impacting frac crew availability limited our ability to bring these wells on-line in the first quarter. Our four well pad in PCU#9 encountered high initial pressures, proving the benefits of the waterflood work to pre-pressurize the reservoir in advance of drilling the pad. The first three wells came on production March 31, showing high total fluid rates and are currently being optimized. Our two well pad in PCU#11 came on production at the end of April and also had encouraging initial tests while being optimized.
Despite positive initial pressure results, our first quarter Deep Basin Mannville Falher well did not meet rate expectations and is tracking approximately 1,000 boe per day behind our forecast. The well was drilled in the Falher formation within the Mannville group, and the underperformance is mostly made up of natural gas. Liquids yields came in as expected at 64 bbl per mmcf, or 210 bbl per day. The well was placed in channel throughout the entire length of the well; however, the reservoir had less permeability than anticipated. This well is still economic due to our owned infrastructure processing advantage and liquids content. We have one Deep Basin well provisionally planned for the third quarter directly offsetting the best well from our 2017 program, in a more extensive channel in the over pressured regime. We maintain significant running room in the Deep Basin amongst multiple formations, and will continue to prove up the acreage as our capital plan allows.
In Peace River, we delivered a strong four well program significantly above type curve initial production rates as we moved back to the heart of Harmon Valley South. Three of our four PROP wells came on line in the first quarter, with average peak rates above 500 bbl per day and 90-day initial production forecasts in the best 10 percent of wells drilled across our acreage. The fourth well came on production late April and has already reached first oil, producing over 500 bbl per day in early May. The joint industry gas gathering system and gas plant is proceeding on schedule, and we expect to have the system on-stream well in advance of the AER Directive-84 regulatory deadline.
Our four well second half Alberta Viking program is highly economic, targeting structural lows to maximize light oil productivity. Pending the results from the ongoing dispositions process, the program may be drilled in the third quarter.
Current Hedging Position
No hedges were added recently as we were already at approved levels for the next 12 months. With the business freeing up from one-time costs in 2018 and potential dispositions impacting both debt and production levels next year, we do not expect to add incremental 2019 hedges at this time. Currently, the Company has the following crude oil hedges in place:
Q2 2018 |
Q3 2018 |
Q4 2018 |
Q1 2019 |
Q2 2019 |
Q3 2019 | ||
WTI $USD |
$50.00 |
$50.05 |
$49.78 |
$50.02 |
$56.53 |
$57.00 | |
bbl/day |
7,000 |
8,000 |
8,000 |
3,000 |
2,000 |
1,000 | |
WTI $CAD |
$71.03 |
$71.04 |
$71.04 |
$67.88 |
$68.58 |
- | |
bbl/day |
5,000 |
4,000 |
4,000 |
6,000 |
4,000 |
- | |
Total |
|||||||
bbl/day |
12,000 |
12,000 |
12,000 |
9,000 |
6,000 |
1,000 |
Additionally, the Company has the following foreign exchange contracts in place:
Currently, the Company has the following natural gas hedges in place:
Q2 2018 |
Q3 2018 |
Q4 2018 | ||
AECO $CAD |
$2.72 |
$2.67 |
$2.67 | |
mcf/day |
22,700 |
17,100 |
15,200 | |
Ventura $USD (1) |
$2.79 |
$2.79 |
$2.79 | |
mcf/day |
7,500 |
7,500 |
7,500 | |
Total |
||||
mcf/day |
30,200 |
24,600 |
22,700 |
(1) |
Through the third quarter of 2020, the Company has an agreement in place to sell 15 mmcf per day of natural gas at the Ventura index price less the cost of transportation from AECO. Recent transportation deductions for the Company to bring product to the Ventura market have been approximately $0.55 per mcf. |
AGM Details
There will be no conference call accompanying these results, as the Company's Annual and Special Meeting (the "Meeting") is scheduled later at 10:00 a.m. MDT (12:00 p.m. EDT). The Meeting will be held in the Acadia Ballroom of the Marriott Downtown Hotel, located at 110 - 9th Avenue SE Calgary, Alberta.
At approximately 10:10 a.m. MDT, and following the formal portion of the Meeting, Mr. David French, President and CEO, will address shareholders and discuss the Company's 2018 first quarter financial and operational results. The Company will host a question and answer period subsequent to the presentation.
To listen to a live broadcast of the presentation and the question and answer period, please access the following URL:
https://event.on24.com/wcc/r/1652072/0971A412DE063422C87144C72F6938B1
A replay of the audio webcast and a link to the Annual and Special Meeting presentation will be available two hours afterwards on our website at www.obsidianenergy.com.
Electronic copies of our Management Information Circular, Proxy Statement, financial statements, news releases, and other public information are available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Abbreviations
Oil |
Natural Gas | ||
bbl |
barrel or barrels |
Mcf |
thousand cubic feet |
bbl/d |
barrels per day |
MMcf |
million cubic feet |
Mbbl |
thousand barrels |
Bcf |
billion cubic feet |
MMbbl |
million barrels |
Mcf/d |
thousand cubic feet per day |
boe/d |
barrels of oil equivalent per day |
MMcf/d |
million cubic feet per day |
Non-GAAP Measures
Certain financial measures including Funds Flow from Operations, Funds Flow from Operations per share-basic, Funds Flow from Operations per share-diluted, netback and net debt included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds Flow from Operations is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of Funds Flow from Operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's netbacks. Net debt includes long-term debt and includes the effects of working capital and all cash held on hand.
Calculation of Funds Flow from Operations
Three months ended March 31 | |||||
(millions, except per share amounts) |
2018 |
2017 | |||
Cash flow from operating activities |
$ |
57 |
$ |
38 | |
Change in non-cash working capital |
(32) |
2 | |||
Decommissioning expenditures |
2 |
4 | |||
Office lease settlements |
5 |
4 | |||
Realized foreign exchange loss – debt maturities |
- |
3 | |||
Carried operating expenses (1) |
- |
4 | |||
Restructuring charges |
1 |
2 | |||
Other expenses |
2 |
- | |||
Funds flow from operations |
$ |
35 |
$ |
57 | |
Per share |
|||||
Basic per share |
$ |
0.07 |
$ |
0.11 | |
Diluted per share |
$ |
0.07 |
$ |
0.11 |
(1) The benefit of carried operating expenses from the Company's partner under PROP was fully utilized in December 2017. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the vast majority of future development capital will flow to Willesden Green primary drilling and will be the key growth driver over the quarters and years to come; that we do not expect to add incremental 2019 hedges at this time; our expectations for full year production and operating costs guidance; that we are well positioned for a strong second half and that we are ready to expand our capital program in Willesden Green with more wells and significant running room in the play pending results from our business development activities; that we continue to see success targeting the Blue Ridge, Nisku and Bakken formations by stimulating and reactivating existing wellbores; that we see meaningful cash flow improvement in 2019 as the business rolls beyond the 2018 hedge book, regulatory capital requirements in Peace River and the third quarter Pound Sterling hedge commitment; that the unshackling of our business in 2019 will provide a marked increase in capital allocated for development focused in Willesden Green; that our operational teams are ready to execute on a robust pipeline of projects to further capitalize our considerable land base; that we expect second quarter absolute operating costs in-line with the first quarter due to higher scheduled turnaround activity, before trending lower in the second half of the year; that availability under the Facility will increase to $440 million on May 29, 2018 to recognize the payment of a senior note maturity; the impact to second quarter production of scheduled turnaround activity; that we expect injection support to mitigate decline rates and meaningfully enhance the ultimate recovery from the four well pad in Willesden Green; the expectation for drilling and timing at various locations; that we maintain significant running room in the Deep Basin amongst multiple groups and formations, and will continue to prove up the acreage as our capital plan allows; that we expect to have the joint industry gas gathering system on-stream well in advance of the AER Directive-84 regulatory deadline; and pending the results of our disposition process, the highly economic Viking program may be drilled.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties other than stated herein; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
View original content:http://www.prnewswire.com/news-releases/obsidian-energy-announces-first-quarter-2018-financial-and-operational-results-300646887.html
SOURCE Obsidian Energy Ltd.
CALGARY, May 1, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") received notification from the New York Stock Exchange (the "NYSE") that we have regained compliance with the NYSE's continued listing standard regarding the price of Obsidian Energy's common stock.
The Company had received notification regarding the price deficiency on March 12, 2018. The NYSE requires that the average closing price of a listed company's common stock be no less than US$1.00 per share over a consecutive 30 trading day period and close above US$1.00 per share on the last trading day of the month to regain compliance. The Company has been notified by the NYSE that it has cured the price condition and regained compliance with all NYSE continued listing requirements as of April 30, 2018.
As outlined in our Management Information Circular and Proxy Statement, the Company will withdraw the share consolidation proposal at the Annual and Special Meeting on May 11, 2018 (the "Meeting") based on the Company regaining compliance with the NYSE's continued listing standard. The withdrawal of this resolution will not affect the validity of the form of proxy enclosed with the Meeting materials, nor the validity of any proxy that has been otherwise already properly submitted. Shareholders still wishing to complete and submit a proxy in relation to the Meeting do not need to indicate their voting instructions on the resolution regarding the share consolidation.
First Quarter Results & Meeting Details
The Company will be releasing its 2018 first quarter financial and operational results before markets open on Friday May 11, 2018. There will be no conference call accompanying the release, as the Company's Meeting is scheduled at 10:00 a.m. MDT (12:00 p.m. EDT) later that morning. The Meeting will be held in the Acadia Ballroom of the Marriott Downtown Hotel, located at 110 - 9th Avenue SE Calgary, Alberta.
At approximately 10:10 a.m. MDT, and following the formal portion of the Meeting, Mr. David French, President and CEO, will address shareholders and discuss the Company's 2018 first quarter financial and operational results. The Company will host a question and answer period subsequent to the presentation.
To listen to a live broadcast of the presentation and the question and answer period, please access the following URL:
https://event.on24.com/wcc/r/1652072/0971A412DE063422C87144C72F6938B1
A replay of the audio webcast will be available two hours after the meeting on our website at www.obsidianenergy.com.
Electronic copies of our Management Information Circular, Proxy Statement, financial statements, news releases, and other public information are available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Obsidian Energy shares are listed on the Toronto Stock Exchange and the New York Stock Exchange under the symbol "OBE".
SOURCE Obsidian Energy Ltd.
GREENWICH, Conn., April 3, 2018 /PRNewswire/ -- FrontFour Capital Group LLC, together with its affiliates ("FrontFour" or "we"), a significant shareholder of Obsidian Energy Ltd. ("Obsidian" or, the "Company") (TSX/NYSE: OBE) with an ownership interest of approximately 6.3% of the Company's outstanding shares, today announced that it has formally provided advance notice to the Company of the nomination of a slate of four highly-qualified candidates for election to the Board of Directors (the "Board") at the Company's 2018 Annual and Special Meeting of Shareholders ("2018 AGM") to be held on May 11, 2018.
FrontFour has also issued the following open letter to Obsidian shareholders:
A LETTER TO THE SHAREHOLDERS OF OBSIDIAN ENERGY LTD.
April 3, 2018
Dear Fellow Shareholders,
As previously disclosed, FrontFour and its principals are significant long-term shareholders of Obsidian, collectively beneficially owning over 31 million shares, representing approximately 6.3% of Obsidian's outstanding shares. In contrast to Obsidian's current Board, our interests are directly aligned with yours. After years of enduring substantial share price underperformance at Obsidian, our goal is to drive significant value creation for the benefit of all Obsidian shareholders.
On April 2, 2018, Obsidian publicly announced that it had commenced a process to explore the sale of the Alberta Viking and Peace River assets as part of an effort to focus on growth in the Cardium. This followed an announcement late last week that Obsidian scheduled its 2018 AGM for May 11, 2018, with a record date of April 4, 2018, although its annual meeting is customarily held in June. We interpret the incumbent Board's action in setting a significantly earlier meeting date as an attempt to minimize the time that FrontFour has to conduct its campaign and use historically low voter turn-out to its advantage.
The Board's Recent Strategic Review Announcement Validates FrontFour's Strategy, is Reactionary and Represents Yet Another About-Face on Strategy
On January 17, 2018, FrontFour first publicly expressed concerns with the Board and laid out an action plan to streamline the Company's asset footprint to focus on becoming a standout light oil growth player and Cardium champion. Obsidian quickly responded by stating that its business plan, centered on sustaining a low-decline production base while leveraging significant development optionality, was working, and that "a change of course would hinder Obsidian's progress."
On March 20, 2018, we announced our intention to nominate four directors for election to the Board, vote against the proposed reverse stock split, and outlined a plan to dispose of Peace River and the Alberta Viking and redeploy the proceeds into debt repayment, stock buybacks and jump-starting production growth in the Cardium. Obsidian almost immediately responded to this with a press release on March 21, 2018 headlined "FrontFour is Risking the Company's Progress."
This is proof positive that Obsidian's Board is out of touch with its shareholder base and in need of significant refreshment. We strongly disagree that Obsidian's stated strategy as of June 2017 represents "progress" when it has led to anemic production and cash-flow growth, a track record of blown operating targets and disastrous hedge losses culminating in the receipt of a NYSE delisting notice.
It is also quite remarkable that less than two weeks after decrying FrontFour's articulated strategy as "risking [the Company's] progress," Obsidian has now announced its intention to implement ALL publicly disclosed aspects of FrontFour's value creation plan, with David French claiming, "[t]oday's announcement is the natural next step in our ongoing strategy to unlock shareholder value and establish Obsidian Energy as a growth company focused on optimizing our industry-leading position in the Cardium." This announcement is anything but "natural" and represents another clear about-face on strategy.
Obsidian's proposed asset sales and related strategic process are clearly material developments. In commenting upon them, Board chair Jay Thornton noted that "[t]he process started in Q3 last year and accelerated in October when the Board selected RBC Capital Markets as our lead financial advisor." This flies in the face of recent trading activity by Obsidian's directors. Over the last few months, Obsidian directors have made market purchases of Obsidian shares, including as recently as March 13, 2018. Had the so-called process including asset sales been fulsome and truly active, then insiders would have been precluded from trading Obsidian shares. The insider purchases suggest that Obsidian's April 2nd strategic review announcement is a recent development and a reaction to significant shareholder pressure.
Obsidian Insider Activity | |||
Director |
Trade Date |
Action |
# of Shares |
George Brookman |
2/5/2018 |
Buy |
10,000 |
John Brydson |
1/19/2018 |
Buy |
336,723 |
John Brydson |
1/22/2018 |
Buy |
163,277 |
Ray Crossley |
3/13/2018 |
Buy |
7,500 |
David French |
2/2/2018 |
Buy |
50,000 |
David French |
2/6/2018 |
Buy |
50,000 |
Maureen Cormier Jackson |
12/14/2017 |
Buy |
30,000 |
Jay Thornton |
2/9/2018 |
Buy |
100,000 |
The Current Board Has Overseen Significant Value Destruction While Underperforming All Relevant Industry Indices
As evidenced by the chart below, Obsidian's Board has overseen the destruction of significant long-term shareholder value as reflected by the stark underperformance of Obsidian's shares relative to three prominent energy indices: (i) the S&P/Canadian Energy Index (XEG ETF), (ii) the Energy Select Sector Index (XLE ETF), and (iii) the S&P Oil & Gas Exploration & Production Select Industry index (XOP ETF).
Astonishingly, Obsidian's shares have traded down approximately 96% during the tenure of George Brookman as a director and 45% since David French became CEO in October of 2016.
OBE Stock Price Performance Under Current Directors Absolute Price Performance Date Since Joining Board Joined OBE XEG XLE XOP Director Board Stock ETF ETF ETF George Brookman 8/3/2005 -95.9% -39.1% 38.5% NA Jay W. Thornton 6/26/2013 -88.3% -25.7% -14.0% -39.7% John Brydson 6/4/2014 -87.7% -44.1% -29.4% -54.2% Raymond D. Crossley 3/6/2015 -41.4% -19.0% -12.2% -28.5% William A. Friley 3/12/2015 -32.5% -15.9% -10.0% -26.3% Maureen Cormier Jackson 3/8/2016 -15.7% 5.6% 12.8% 27.4% David L. French 10/24/2016 -44.6% -15.9% -3.7% -6.0% Gordon Ritche 12/12/2017 -15.1% -5.1% -3.1% 0.1% Edward Kernaghan 1/3/2018 -22.8% -11.4% -9.6% -8.8% Calculated as of 3/29/18. Excludes dividends. Note: XOP ETF launched in June 2006.
The Board's disastrous historical record of oversight of management's repeated strategic missteps has resulted in an overhang on Obsidian's share price that, despite the recent announcement, in our view may only be lifted by a substantial overhaul in Board composition. We now urge our fellow shareholders to support FrontFour's efforts to drive value for all shareholders.
Board Compensation: Taking Equity at the Bottom
In Obsidian's April 2nd press release, the Board announced their intention to receive all director fees in equity in lieu of cash. We find it interesting that the Board waited until now to finally align their interests with shareholders. As depicted in the charts below, the Board's historical actions have been anything but aligned. Per Obsidian's two most recent information circulars, only one director elected to receive more than 50% of his or her Board compensation in share-based awards. Additionally, as of the most recently available public data, four directors currently own significantly less than the minimum 100,000 share requirement, including George Brookman, despite his nearly 13-year Board tenure.
Obsidian Board Compensation (2015 to 2016) | ||||||||
Cash Fees Received |
Share-Based Awards |
Total Compensation |
% Cash of Total | |||||
Director |
2015 |
2016 |
2015 |
2016 |
2015 |
2016 |
2015 |
2016 |
George Brookman |
$115,017 |
$89,125 |
$24,817 |
$21,875 |
$139,834 |
$111,000 |
82% |
80% |
John Brydson |
- |
- |
$142,834 |
$115,500 |
$142,834 |
$115,500 |
0% |
0% |
Raymond Crossley |
$73,181 |
$88,313 |
$43,056 |
$34,688 |
$116,237 |
$123,001 |
63% |
72% |
William Friley |
$90,063 |
$93,750 |
$16,875 |
$18,750 |
$106,938 |
$112,500 |
84% |
83% |
Maureen Cormier Jackson |
NA |
57,391 |
NA |
$30,391 |
NA |
$87,782 |
NA |
65% |
Jay Thornton |
$69,748 |
$54,750 |
$69,748 |
$54,750 |
$139,496 |
$109,500 |
50% |
50% |
Gordon Ritche |
NA |
NA |
NA |
NA |
NA |
NA |
NA |
NA |
Edward Kernaghan |
NA |
NA |
NA |
NA |
NA |
NA |
NA |
NA |
Source: Obsidian public filings. |
||||||||
NA denotes that individual was not on the Board of Directors during years listed. |
The stated intention in the Company's April 2nd announcement is simply too little, too late. While Obsidian's shareholders have suffered significant losses, a majority of Obsidian's legacy directors (excluding Ritchie and Kernaghan) have continued to enrich themselves by electing to take the vast majority of their director compensation in cash.
Independent Director Equity Ownership | |||
Director |
Shares (#) |
DSUs (#) |
Total Equity (#) |
George Brookman |
30,000 |
51,693 |
81,693 |
John Brydson |
2,553,000 |
196,799 |
2,749,799 |
Raymond Crossley |
19,000 |
52,610 |
71,610 |
William Friley |
50,648 |
26,615 |
77,263 |
Maureen Cormier Jackson |
35,000 |
24,677 |
59,677 |
Jay Thornton |
288,750 |
112,689 |
401,439 |
Gordon Ritchie |
100,000 |
NA |
100,000 |
Edward Kernaghan |
34,791,375 |
NA |
34,791,375 |
Sources: Obsidian 2017 Management Circular & Subsequent Public Filings | |||
Gordon Ritchie and Ed Kernaghan DSUs have not yet been disclosed | |||
Edward Kernaghan's shareholdings includes all Kernaghan controlled entities |
FrontFour's Highly- Qualified Director Nominees Will Bring Technical Expertise, Oversight and Accountability to Help Steward Obsidian's Asset Optimization Strategy
As long-term shareholders, our goal is to hold the Board accountable for their performance and to ensure that the Board's interests are aligned with those of shareholders. Given the Obsidian Board's poor track record, continued failure to communicate, let alone execute, a clear and consistent corporate strategy to investors and the misalignment of the Board's interests with those of shareholders, we believe substantial change is warranted, especially as industry consolidation in the Cardium appears on the horizon. The incumbent Board cannot be counted on to take the appropriate value maximizing steps. Accordingly, FrontFour has formally provided advance notice of the nomination of four highly qualified nominees. If elected, we expect that our nominees would spearhead the implementation of a revised corporate strategy focused on streamlining the Company portfolio and growing Obsidian's light oil-weighted production in the Cardium. Our nominees would bring significant technical and financial expertise, as well as additional fresh perspectives and renewed accountability, to Obsidian's Board for the benefit of all shareholders. We are highly confident that such a dynamic will put Obsidian on a path towards unlocking the significant shareholder value embedded within its asset base.
Quite clearly, the incumbent Board has failed shareholders and has a demonstrable track record of entrenchment. When FrontFour approached the Board in October 2017 as part of an effort to work constructively and privately towards unlocking value for shareholders, their immediate reaction was to take aggressive and defensive steps towards entrenchment and self-preservation, as opposed to anything related to enhancing shareholder value. When FrontFour stood firm, the Board opted to install Edward Kernaghan onto the Board, despite having resisted doing so since March 2016. This was principally due to Mr. Kernaghan's ability to further entrench the incumbent Board by virtue of his willingness to sign an off-market standstill and voting agreement obliging him to vote blindly for Obsidian's slate at the 2018 AGM. This behavior – on both sides of the negotiation – is a prime example of the insular, "clubby" mentality that now permeates Obsidian's boardroom to the detriment of shareholders. FrontFour and its nominees are committed to changing this culture for the benefit of all shareholders.
Over the coming weeks, we look forward to engaging with you.
Biographies of FrontFour's Nominees:
Steven P. Evans
Mr. Evans had a 31-year career with Chevron / Texaco until his retirement in 2012. Most recently he held the position of general manager, North America exploration at Chevron.
Michael J. Faust
Mr. Faust has 34 years of industry, financial and leadership experience within the oil and gas sector, including diverse geological, geophysical and technical reservoir experience spanning many different basins and formations throughout the world.
Matthew ("Matt") Goldfarb
Mr. Goldfarb has over 20 years of diverse experience as an investor, in senior management roles at companies undergoing financial restructurings, legal counsel, and board director across numerous industries where he has helped drive successful outcomes for shareholders.
Stephen E. Loukas
Mr. Loukas has nearly 20 years of experience as an investor, investment banker, and financial restructuring consultant with significant experience across a broad-based number of industries.
Sincerely,
Zachary R. George Portfolio Manager |
David A. Lorber Portfolio Manager |
Stephen E. Loukas Portfolio Manager |
FRONTFOUR CAPITAL GROUP LLC
FrontFour Capital Group LLC, located in the United States at 35 Mason Street, Greenwich, CT 06830, was formed in December 2006. FrontFour Capital Group LLC is registered with the Securities & Exchange Commission as an investment adviser under the Investment Advisers Act of 1940, as amended.
ADDITIONAL INFORMATION CONCERNING FRONTFOUR'S PROPOSED BOARD NOMINEES
Name |
Present Principal Occupation, Business or |
Number of |
Steven P. Evans |
Retired since 2013. Prior to his retirement, Mr. Evans was VP- Head of Exploration for North America for Chevron. |
Nil |
Michael J. Faust |
Currently a consultant at Quartz Geophysical LLC, a geophysical consulting firm, and a director at SAExploration Holdings, Inc., an oilfield services firm. Prior thereto, Mr. Faust was Vice President Exploration, Business Development and Land (August 2013 to January 2017) and Chukchi Sea Project Manager (until August 2013) for ConocoPhillips Alaska, Inc., an oil and gas company. |
Nil |
Matthew Goldfarb |
Founding partner and managing member of Southport Midstream Partners LLC (since the first quarter of 2016), a private-equity backed investment vehicle focused on energy infrastructure projects in North America, and (since December 2013) Chief Restructuring Officer and Acting Chief Executive Officer of Cline Mining Corporation, a Canadian mining company whose primary asset is the New Elk coking coal mine in Weston, Colorado. Prior thereto, Mr. Goldfarb was Chief Executive Officer of Xinergy Ltd., a coal mining company, from May 2012 until November 2013. |
124,500 |
Stephen E. Loukas |
Managing Member and Portfolio Manager of FrontFour Capital Group LLC, a hedge fund. |
259,400 |
Each of FrontFour's proposed Board nominees has been indemnified by affiliates of FrontFour in connection with such Board nominee's nomination for election at the 2018 AGM, and Messrs. Evans, Faust and Goldfarb have each provided a power of attorney in favour of Stephen E. Loukas for the purposes of various corporate and securities law filings in connection with the 2018 AGM and related matters.
Penalties or Sanctions
To the knowledge of FrontFour, none of FrontFour's proposed Board nominees has: (i) been subject to any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority; or (ii) been subject to any other penalties or sanctions imposed by a court or regulatory body that would be likely to be considered important to a reasonable security holder in deciding whether to vote for a proposed director.
Individual Bankruptcies
To the knowledge of FrontFour, none of FrontFour's proposed Board nominees is or has, within the 10 years prior to the date hereof, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold the assets of that individual.
Corporate Cease Trade Orders or Bankruptcies
To the knowledge of FrontFour and except as set out below, none of FrontFour's proposed Board nominees is, or has been within the past ten years, a director or executive officer of any company that, while such person was acting in that capacity: (i) was the subject of a cease trade or similar order or an order that denied the relevant company access to any exemptions under securities legislation that was in effect for a period of more than 30 consecutive days; (ii) was subject to an event that resulted, after that individual ceased to be a director or executive officer, in the company being the subject of a cease trade or similar order or an order that denied the company access to any exemptions under securities legislation that was in effect for a period of more than 30 consecutive days; or (iii) within a year of that individual ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets.
In December 2013, and in contemplation of a financial restructuring, Mr. Goldfarb was retained by the Cline Mining Corporation board of directors, at the instruction of its senior lenders, to lead the financial restructuring and optimization of the mining assets of the Toronto Stock Exchange-listed issuer. Companies' Creditors Arrangement Act (Canada) ("CCAA") insolvency proceedings and related Chapter 15 "recognition" proceedings relating to the "work-out" of Cline Mining Corporation were initiated in December 2014, and the company emerged therefrom in July 2015.
On June 22, 2015, Midway Gold Corporation and certain of its subsidiaries filed voluntary petitions for relief under Chapter 11 of the Bankruptcy Code in the United States Bankruptcy Court for the District of Colorado, seeking ancillary relief in Canada pursuant to the CCAA in the Supreme Court of British Columbia in Vancouver, Canada. On January 29, 2016, Mr. Goldfarb was appointed as an independent director of Midway to assist the issuer in its ongoing financial restructuring and asset-sale efforts.
In connection with Obsidian's 2018 AGM, FrontFour intends to file a dissident information circular in due course. FrontFour is providing the following disclosure required under section 9.2(4) of National Instrument 51-102 – Continuous Disclosure Obligations in accordance with securities laws applicable to public broadcast solicitations. Any solicitation made by FrontFour will be made by it and not by or on behalf of the management of Obsidian. All costs incurred for any solicitation will be borne by FrontFour, provided that, subject to applicable law, FrontFour may seek reimbursement from Obsidian of FrontFour's out-of-pocket expenses, including proxy solicitation expenses and legal fees, incurred in connection with any successful result at a meeting of Obsidian shareholders. Proxies may be solicited by FrontFour pursuant to an information circular sent to shareholders after which solicitations may be made by or on behalf of FrontFour by mail, telephone, fax, email or other electronic means as well as by newspaper or other media advertising, and in person by directors, officers and employees of FrontFour, who will not be specifically remunerated therefor. FrontFour may also solicit proxies in reliance upon the public broadcast exemption to the solicitation requirements under applicable Canadian corporate and securities laws, including through press releases, speeches or publications, and by any other manner permitted under applicable Canadian laws. FrontFour may engage the services of one or more agents and authorize other persons to assist in soliciting proxies on its behalf, which agents would receive customary fees for such services. In particular, The Laurel Hill Advisory Group Company (the "Proxy Solicitor") has been engaged to solicit proxies in the United States and Canada. Pursuant to this engagement, the Proxy Solicitor will receive an initial fee of C$100,000 plus a customary fee for each call to and from shareholders. In addition, the Proxy Solicitor may be entitled to a fee of up to C$125,000 in connection with a successful solicitation campaign. Proxies may be revoked by instrument in writing by a shareholder giving the proxy or by its duly authorized officer or attorney, or in any other manner permitted by law and the articles or by-laws of Obsidian. None of FrontFour nor, to its knowledge, any of its associates or affiliates, has any material interest, direct or indirect: (i) in any transaction since the beginning of Obsidian's most recently completed financial year or in any proposed transaction that has materially affected or would materially affect Obsidian or any of its subsidiaries; or (ii) by way of beneficial ownership of securities or otherwise, in any matter proposed to be acted on by Obsidian, other than the election of directors to the board of Obsidian. Obsidian's principal office address is 200, 207 - 9th Avenue SW Calgary, Alberta T2P 1K3.
CONTACT
Investor Contact:
Stephen Loukas
FrontFour Capital Group LLC
35 Mason Street, 4th Floor
Greenwich, CT 06830
203-274-9050
SOURCE FrontFour Capital Group LLC
-- Launches Sale Process for Alberta Viking Assets; Ongoing Discussions with CIC Regarding Disposition of PROP; Plans to Use Any Sale Proceeds to Fund Cardium Growth, Reduce Debt and Buy Back Shares --
CALGARY, April 2, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") has retained RBC Capital Markets to explore a potential sale of the Company's Alberta Viking assets and is engaged in ongoing discussions with China Investment Corporation ("CIC") regarding a disposition of the Company's share of jointly owned Peace River assets. Obsidian Energy intends to use the proceeds of any such asset sales to accelerate growth in the Company's prime Cardium assets, pay down debt and return capital to shareholders through the implementation of a Normal Course Issuer Bid.
The Company is also announcing a deferral of the proposed share consolidation and changes to Obsidian Energy's Director compensation to further align director pay with shareholders.
"Today's announcement is the natural next step in our ongoing strategy to unlock shareholder value and establish Obsidian Energy as a growth company focused on optimizing our industry-leading position in the Cardium," said David French, President and CEO of Obsidian Energy. "In addition to exploring the sale of our Alberta Viking and Peace River assets, we are actively reviewing industry consolidation opportunities with significant synergies and a focus on creating a company with best-in-class operating performance, financial discipline and industry-leading growth prospects."
Over the past three years, Obsidian Energy has divested approximately $2.3 billion of assets, significantly improved the Company's financial and operating performance and eliminated a number of the legacy challenges that have constrained the Company's relative performance.
"Obsidian Energy's Board and management are working with a sense of purpose – and opportunity – to create value for all shareholders," said Jay Thornton, Board Chair. "This process started in Q3 last year and accelerated in October when the Board selected RBC Capital Markets as our lead financial advisor to work alongside management to action any and all value creating transactions. We believe in the Company's future and are excited about its potential."
With production of approximately 2,500 boe/d, the Alberta Viking asset offers a mix of light-oil and gas with high-netback shorter cycle wells, an industry-leading land position and extensive owned infrastructure over the entire Esther area. The Peace River Oil Partnership ("PROP") is a joint venture between Obsidian Energy and CIC, with net production to Obsidian Energy of approximately 5,000 boe/d and a large position in a crude oil resource highly amenable to conventional cold-flow production. PROP has de-risked its large resource base and has many years of inventory with attractive economics.
The Company expects to conclude a sale of the Alberta Viking assets by the end of the second quarter of 2018. Discussions with CIC are expected to continue into the fall before a formal process is started.
Planned Use of Proceeds
The Board will determine the right balance of accelerated Cardium growth, debt repayment and share buybacks based on changes in the Company's borrowing base as a result of any production being sold, and Obsidian Energy's share price at the time of any such sale. The Company intends to apply for a Notice of Intention to Make a Normal Course Issuer Bid (the "Bid") with the Toronto Stock Exchange (the "TSX") upon closing of the potential transaction. The Bid will be subject to the approval of the TSX and the Company's lenders. Obsidian Energy intends to repurchase shares on both the TSX and New York Stock Exchange (the "NYSE") and/or alternative Canadian trading systems.
Proposed Share Consolidation to Cure NYSE Listing Requirements to Be Deferred, or Otherwise Cancelled
Obsidian Energy previously announced its intention to propose a consolidation of the Company's outstanding common shares at the upcoming Annual and Special Meeting, subject to Board discretion. The Board and management have listened to investor feedback encouraging the Board not to proceed with the share consolidation at this time. Moreover, the Board and management strongly believe that the continued execution of the Company's strategy will bring Obsidian Energy into compliance with the NYSE's listing requirements within the applicable time frame. The Board will, however, continue to seek the discretion to consolidate the common shares, on the same ratio as previously stated, but only in the event that the Company is not in compliance with the minimum share price listing standard on the latest date necessary to potentially avoid the delisting from the NYSE.
Obsidian Energy Directors Elect to Receive All Fees in Equity versus Cash
As an expression of confidence in the Company's future and to even more firmly align the interests of Directors with the interests of Obsidian Energy shareholders, each member of the Board of Directors has elected to take all of his or her fees in the form of equity (e.g. Deferred Share Units) going forward.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and the New York Stock Exchange under the symbol "OBE.BC".
OBSIDIAN ENERGY: Suite 200, 207 - 9th Avenue SW, Calgary, Alberta T2P 1K3, Phone: 403-777-2500, Fax: 403-777-2699, Toll Free: 1-866-693-2707, Website: www.obsidianenergy.com; Investor Relations: Toll Free: 1-888-770-2633, E-mail: investor_relations@obsidianenergy.com
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: a potential sale of the Company's Alberta Viking assets and the engagement of discussions with CIC regarding a disposition of the Company's share of jointly owned Peace River assets; how the Company intends to use the proceeds of any such asset sales; that we are actively reviewing industry consolidation opportunities with significant synergies and are focusing on creating a company with best-in-class operating performance, financial discipline and industry-leading growth prospects; that we believe in the Company's future and are excited about its potential; that PROP has de-risked its large resource base and has many years of inventory with attractive economics; the timing for potential sales and discussions to occur; that the Company intends to apply for a Bid, the expected timing for doing so and where it intends to repurchase those shares; the belief that the continued execution of the Company's strategy will bring Obsidian Energy into compliance with the NYSE's listing requirements within the applicable time frame; that the Company will continue to seek to consolidate the common shares only on the reasons set forth; and that each of the members of the Board Of Directors will take their fees in the form of equity going forward.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions, or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, March 20, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX – OBE, NYSE – OBE.BC) ("Obsidian Energy", the "Company", "we", "us" or "our") comments on FrontFour Capital Group LLC's ("FrontFour") intention to nominate four candidates to stand for election at the Company's 2018 Annual General Meeting.
Jay Thornton, Chairman of the Obsidian Energy Board of Directors (the "Board"), commented, "We are disappointed that after several months of attempting to work constructively with FrontFour, including the addition of Gord Ritchie to the Board at their suggestion, FrontFour has chosen to put its interests ahead of other shareholders at a critical time in the Company's history by starting a costly, time consuming, and distracting proxy fight. Obsidian Energy has a refreshed Board with significant shareholder representation that is committed to value creation in both the short and long term. We recognize that status quo is not an option and have been pursuing attractive commercial opportunities to reward investors. FrontFour's unnecessary agenda only adds undue risk to the execution of these outcomes."
Gordon Ritchie, one of the newest members of the Board stated, "I am in a position to say the strategic points raised by FrontFour have undergone extensive scrutiny by management and the Board. As communicated to FrontFour and all shareholders, we are aggressively looking at all options to increase shareholder value. This is a challenging investment environment for all Canadian E&P, but I am confident when I say Obsidian Energy is on the right track and David French and his group are the right team to execute."
Obsidian Energy will have more to say on FrontFour's agenda in due course. In the meantime, the Board and management team remain focused on executing our strategic plan to deliver strong results on behalf of all shareholders.
Shareholders do not need to take any action at this time regarding voting at the Annual General Meeting.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and the New York Stock Exchange under the symbol "OBE.BC".
OBSIDIAN ENERGY: Suite 200, 207 - 9th Avenue SW, Calgary, Alberta T2P 1K3, Phone: 403-777-2500, Fax: 403-777-2699, Toll Free: 1-866-693-2707, Website: www.obsidianenergy.com; Investor Relations: Toll Free: 1-888-770-2633, E-mail: investor_relations@obsidianenergy.com
KINGSDALE ADVISORS: Ian Robertson, Executive Vice President, Communication Strategy, Direct: 416-867-2333, Cell: 647-621-2646, E-mail: irobertson@kingsdaleadvisors.com
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we are committed to value creation in both the short and long term; that we are aggressively looking at all options to increase shareholder value; that the Company is on the right track and David French and his group are the right team to execute; that will have more to say on FrontFour's agenda in due course; and that the Board and management team remain focused on executing our strategic plan to deliver strong results on behalf of all shareholders.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions, or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
GREENWICH, Conn., March 20, 2018 /PRNewswire/ -- FrontFour Capital Group LLC together with its affiliates, a significant shareholder of Obsidian Energy Ltd. ("Obsidian" or the "Company") (TSX/NYSE: OBE), today issued an open letter to the Company's stockholders. The full text of the letter follows:
March 20, 2018
Dear Fellow Shareholders,
As previously disclosed, FrontFour Capital Group LLC (together with its affiliates, "FrontFour" or "we") and its principals are significant long-term shareholders of Obsidian, collectively beneficially owning over 31 million shares, representing approximately 6.2% of Obsidian's outstanding shares. Since issuing our first public letter to shareholders on January 17, 2018, Obsidian's shareholders have expressed a common theme of frustration with Obsidian's inconsistent and unsound strategic plan, flawed hedging strategy and poor leadership team. Accordingly, we are announcing our intention to nominate four highly qualified directors for election at Obsidian's 2018 annual general meeting. We intend to formally nominate our highly qualified candidates once the meeting has been called.
In the weeks to come, FrontFour will release its detailed value creation strategy at Obsidian, initially centered on streamlining the Company's organizational profile via:
Obsidian has the ability to aggressively shift the drilling program to the higher return Cardium, where the Company has a deep and enviable inventory. Given the size and resources of Obsidian it is very important to bring focus to the portfolio. While the Alberta Viking and Peace River are both attractive assets, for Obsidian they are non-core and should be monetized. Given that multiple parties have expressed interest to FrontFour in such assets, should they become available, we strongly believe this is an executable course of action.
We believe the monetization of the Alberta Viking, Peace River and the remaining non-core legacy assets would result in:
In turn, FrontFour's value creation strategy would focus on re-deploying the proceeds from the divestitures of the Alberta Viking and Peace River in the following manner:
On March 12, 2018, Obsidian announced a proposed 1:3 reverse stock split to be voted on at its 2018 annual general meeting. This proposal is in response to a notification from the New York Stock Exchange ("NYSE") that the Company was no longer in compliance with one of the NYSE's continued listing standards because the average closing price of Obsidian was less than US$1.00 per share over a consecutive 30 trading day period. FrontFour will be voting against the reverse stock split proposal. The historic track record of subsequent stock price performance by companies that execute reverse stock splits from perceived positions of weakness is very poor. Furthermore, the proposal by management and the board of directors (the "Board") signals to us that they themselves may lack confidence in their operating and strategic plan to catalyze the stock price sustainably above US$1.00.
In contrast, it is our strong belief that our plan would result in a value proposition for investors that would be valued significantly higher by the public equity markets and would quickly result in Obsidian being back in compliance with NYSE listing standards. We believe our nominees' strong collective technical and operational expertise within the energy industry, coupled with significant financial and strategic experience across numerous complex situations, will bring a fresh perspective to the Board and will help drive the necessary decisions needed to close the significant value gap between Obsidian's current stock price relative to its intrinsic value.
Biographies of FrontFour's Nominees:
Steven P. Evans
Mr. Evans had a 31-year career with Chevron / Texaco until his retirement in 2012. Most recently held the position of general manager, North America exploration at Chevron.
Michael J. Faust
Mr. Faust has 34 years of industry, financial and leadership experience within the oil and gas sector, including diverse geological, geophysical and technical reservoir experience spanning many different basins and formations throughout the world.
Matthew ("Matt") Goldfarb
Mr. Goldfarb has over 20 years of diverse experience as an investor, senior management roles at companies undergoing financial restructurings, legal counsel, and board director across numerous industries where he has helped drive successful outcomes for shareholders.
Stephen E. Loukas
Mr. Loukas has nearly 20 years of experience as an investor, investment banker, and financial restructuring consultant with significant experience across a broad-based number of industries.
As stated in our January 17th letter to Obsidian's shareholders, we worked tirelessly to come to an amicable agreement with Obsidian's Board on the addition to the Board of one mutually agreed upon independent nominee proposed by FrontFour, as part of an effort to work constructively with the Company to maximize shareholder value. In response, Obsidian's Board issued a defensive and inaccurate press release stating that it had negotiated in good faith, but that FrontFour had refused to sign the same agreement executed by Edward (Ed) H. Kerneghan in connection with his appointment to the Board. The time has come for FrontFour to set the record straight. Some of the settlement terms proposed by Obsidian at various times were as follows:
These and other terms proposed by Obsidian were off-market in the context of a settlement agreement of this nature. Neither FrontFour nor any sophisticated institutional shareholder would, consistent with their fiduciary obligations to their investors, effectively hand over blank proxies to Obsidian's management and existing Board. However, most importantly, we believe agreeing to these terms would have further entrenched this Board and resulted in an extension of the value destructive status quo at Obsidian.
We are committed, long-term investors with a strong track record of alignment and value creation in situations where we have sought change. We believe that significant upside exists in Obsidian's shares from current levels. The current Board has had ample time and opportunity to identify and unlock that value, but has failed. The time for change at Obsidian has come.
Sincerely,
Zachary R. George Portfolio Manager |
David A. Lorber Portfolio Manager |
Stephen E. Loukas Portfolio Manager |
FRONTFOUR CAPITAL GROUP LLC
FrontFour Capital Group LLC, located in the United States at 35 Mason Street, Greenwich, CT 06830, was formed in December 2006. FrontFour Capital Group LLC is registered with the Securities & Exchange Commission as an investment adviser under the Investment Advisers Act of 1940, as amended.
ADDITIONAL INFORMATION CONCERNING FRONTFOUR'S PROPOSED BOARD NOMINEES
Name |
Present Principal Occupation, Business or Employment and in Five Preceding Years |
Number of Common Shares of Obsidian Beneficially Owned or Controlled |
Steven P. Evans |
Retired since 2013. Prior to his retirement, Mr. Evans was VP- Head of Exploration for North America for Chevron. |
Nil |
Michael J. Faust |
Currently a consultant at Quartz Geophysical LLC. Prior thereto, Mr. Faust was Vice President Exploration, Business Development and Land for ConocoPhillips Alaska, Inc. |
Nil |
Matthew Goldfarb |
Founding partner and managing member of Southport Midstream Partners LLC |
124,500 |
Stephen E. Loukas |
Managing Member and Portfolio Manager of FrontFour Capital Group LLC. |
254,650 |
Each of FrontFour's proposed board nominees has been indemnified by an affiliate of FrontFour in connection with such board nominee's nomination for election at Obsidian's 2018 Annual General Meeting.
Penalties or Sanctions
To the knowledge of FrontFour, none of FrontFour's proposed board nominees, has: (i) been subject to any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority; or (ii) been subject to any other penalties or sanctions imposed by a court or regulatory body that would be likely to be considered important to a reasonable security holder in deciding whether to vote for a proposed director.
Individual Bankruptcies
To the knowledge of FrontFour, none of FrontFour's proposed board nominees is or has, within the 10 years prior to the date hereof, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold the assets of that individual.
Corporate Cease Trade Orders or Bankruptcies
To the knowledge of FrontFour and except as set out below, none of FrontFour's proposed board nominees is, or has been within the past ten years, a director or executive officer of any company that, while such person was acting in that capacity: (i) was the subject of a cease trade or similar order or an order that denied the relevant company access to any exemptions under securities legislation that was in effect for a period of more than 30 consecutive days; (ii) was subject to an event that resulted, after that individual ceased to be a director or executive officer, in the company being the subject of a cease trade or similar order or an order that denied the company access to any exemptions under securities legislation that was in effect for a period of more than 30 consecutive days; or (iii) within a year of that individual ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets.
In December 2013, and in contemplation of a financial restructuring, Mr. Goldfarb was retained by the Cline Mining Corporation board of directors, at the instruction of its senior lenders, to lead the financial restructuring and optimization of the mining assets of the Toronto Stock Exchange-listed issuer. Companies' Creditors Arrangement Act (Canada) ("CCAA") insolvency proceedings and related Chapter 15 "recognition" proceedings relating to the "work-out" of Cline Mining Corporation were initiated in December 2014, and the company emerged therefrom in July 2015.
Mr. Goldfarb resigned as CEO of Xinergy, Ltd. in November 2013. Xinergy filed for bankruptcy protection under Chapter 11 in July 2015 due to challenging market conditions, given its exposure to metallurgical coal pricing.
On June 22, 2015, Midway Gold Corporation and certain of its subsidiaries filed voluntary petitions for relief under Chapter 11 of the Bankruptcy Code in the United States Bankruptcy Court for the District of Colorado, seeking ancillary relief in Canada pursuant to the CCAA in the Supreme Court of British Columbia in Vancouver, Canada. On January 29, 2016, Mr. Goldfarb was appointed as an independent director of Midway to assist the issuer in its ongoing financial restructuring and asset-sale efforts.
The information contained in this news release does not and is not meant to constitute a solicitation of a proxy within the meaning of applicable securities laws. Although FrontFour intends to nominate the proposed nominees for election at Obsidian's 2018 Annual General Meeting, there is currently no record or meeting date and Obsidian shareholders are not being asked at this time to execute a proxy in favour of any matter, including the proposed nominees. In connection with Obsidian's 2018 Annual General Meeting, FrontFour may file a dissident information circular in due course in compliance with applicable securities laws. Notwithstanding the foregoing, FrontFour is voluntarily providing the disclosure required under section 9.2(4) of National Instrument 51-102 – Continuous Disclosure Obligations in accordance with securities laws applicable to public broadcast solicitations. Any solicitation made by FrontFour will be made by it and not by or on behalf of the management of Obsidian. All costs incurred for any solicitation will be borne by FrontFour, provided that, subject to applicable law, FrontFour may seek reimbursement from Obsidian of FrontFour's out-of-pocket expenses, including proxy solicitation expenses and legal fees, incurred in connection with any successful result at a meeting of Obsidian shareholders. Proxies may be solicited by FrontFour pursuant to an information circular sent to shareholders after which solicitations may be made by or on behalf of FrontFour by mail, telephone, fax, email or other electronic means as well as by newspaper or other media advertising, and in person by directors, officers and employees of FrontFour, who will not be specifically remunerated therefor. FrontFour may also solicit proxies in reliance upon the public broadcast exemption to the solicitation requirements under applicable Canadian corporate and securities laws, including through press releases, speeches or publications, and by any other manner permitted under applicable Canadian laws. FrontFour may engage the services of one or more agents and authorize other persons to assist in soliciting proxies on its behalf, which agents would receive customary fees for such services. Once FrontFour has commenced any solicitation of proxies, proxies may be revoked by instrument in writing by a shareholder giving the proxy or by its duly authorized officer or attorney, or in any other manner permitted by law and the articles or by-laws of Obsidian. None of FrontFour nor, to its knowledge, any of its associates or affiliates, has any material interest, direct or indirect: (i) in any transaction since the beginning of Obsidian's most recently completed financial year or in any proposed transaction that has materially affected or would materially affect Obsidian or any of its subsidiaries; or (ii) by way of beneficial ownership of securities or otherwise, in any matter proposed to be acted on by Obsidian, other than the election of directors to the board of Obsidian. Obsidian's principal office address is 200, 207 - 9th Avenue SW Calgary, Alberta T2P 1K3.
CONTACT
Investor Contact:
Stephen Loukas
FrontFour Capital Group LLC
35 Mason Street, 4th Floor
Greenwich, CT 06830
203-274-9050
View original content:http://www.prnewswire.com/news-releases/frontfour-releases-letter-to-obsidian-shareholders-300617073.html
SOURCE FrontFour Capital Group LLC
CALGARY, March 7, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the year ended December 31, 2017. All figures are in Canadian dollars unless otherwise stated. Obsidian Energy's Management Discussion and Analysis ("MD&A") dated March 6, 2018 and audited financial statements for year end 2017 can be found on our website at www.obsidianenergy.com. The documents will also be filed on SEDAR and EDGAR in due course.
"We are pleased to report an excellent fourth quarter and full year results," commented David French, President & CEO. "2017 was a breakthrough year for the Company. Notwithstanding a challenging external environment, we consistently delivered on our operational objectives, beat our production guidance, and underpinned the shallow decline cash flows of the business. We grew our A&D adjusted production base in 2017 by approximately 10 percent, kick-starting a disciplined growth story, even while spending less capital and maintaining our focus on balance sheet strength.
We continue to deliver strong results across our field operations, specifically within our Cardium acreage. Off the back of these results, we have found ways to put additional dollars to work in the highly economic Willesden Green fairway. The success of our 2017 program sets us up well for 2018 and beyond. We see many reasons to be excited for the future of Obsidian Energy."
Delivered Year over Year Production Growth of 10 Percent and Full Year 2017 Production above Guidance
Full year 2017 production was 31,723 boe per day, above the high end of our guidance range of 30,500 – 31,500 boe per day. Ongoing waterflood and our shallow base decline, combined with solid execution of our second half development program drove the outperformance.
Fourth quarter 2017 production was 31,447 boe per day, 10 percent higher than the previous year, adjusted for A&D. Relative to the third quarter, we grew total production and liquids production by four percent. This marks another quarter of consistent production delivery and advances our operational momentum into the first quarter of 2018.
Total 2017 Capital Expenditures Beat Guidance, Including Cardium Drilling Acceleration
Full year 2017 capital was $157 million, including decommissioning expenditures, below our guidance of $160 million. Fourth quarter capital was $44 million, including decommissioning expenditures, highlighted by our first foray into the Deep Basin and bringing on seven Cardium producing wells. We also executed a December start-up of five of our 2018 Cardium wells, while delaying some minor Cardium injector capital into 2018.
Operating Expenses were Comfortably Within Guidance Range
Full year and fourth quarter 2017 operating expenses were $13.40 per boe and $12.50 per boe, respectively, net of carried expenses. Growing production volumes offset higher maintenance and turnaround activity, driving a full year number that was comfortably within our guidance range of $13.00 - $13.50 per boe.
As expected, our Peace River operating cost carry was fully utilized in December. The Company is well positioned for continuous operating cost improvement driven by a dedicated push for efficiency and our recent disposition of high cost legacy assets. As a result, we expect our cost basis, excluding any carry impact, to decrease year over year.
Five Percent Higher Funds Flow from Operations versus 2016, Despite 42 Percent Less Production
Full year Funds Flow from Operations was $192 million, up from $182 million in 2016. Despite meaningful disposition activity in 2016 that reduced production by 42 percent, the increase in FFO was supported by higher crude oil prices and more than $100 million less of gross operating expenses.
Fourth quarter Funds Flow from Operations was $52 million, up from $40 million in the third quarter. Higher benchmark commodity prices, robust field realizations and strong production volumes drove the cash flow performance. Our light oil realizations were in line with benchmark expectations, while heavy oil and natural gas realizations were higher than benchmark pricing.
Heavy oil realized pricing increased by 26 percent relative to the third quarter, compared to a 15 percent increase in Canadian Dollar heavy oil benchmark pricing. Our rail transportation and alternative price basis sales points reinforced the strong realized pricing in the quarter.
A portion of our natural gas volumes are sold relative to a US Midwest market at Ventura. In the fourth quarter of 2017, Obsidian Energy had the benefit of selling approximately 30 mmcf per day into this market. The premium we received at Ventura contributed nearly $5 million additional to Funds Flow from Operations and was mainly due to a short term price spike, where our gas realizations averaged approximately $5.00 per mcf above AECO pricing in December. While a portion of our pricing arrangement ended in 2017, we retain 15 mmcf per day of Ventura marketing commitments through the third quarter of 2020.
Demonstrating Cardium Drilling Consistency; Well Results Command Additional Investment
Following on our recent four well pad in Willesden Green, initial rates from our two 2018 locations are exceeding expectations. The two well pad came on stream February 20 and has averaged approximately 900 boe per day through March 4, implying an average of 450 boe per day per well (88 percent liquids) over that timeframe. These strong initial results demonstrate the regular success we have had optimizing wellbore placement in the bioturbated interval and proven completion design.
We plan to add three wells to our 2018 Willesden Green Cardium program. We expect one of those wells to come on stream in the second quarter, and the next two wells to come on stream early in the fourth quarter. We will fund these wells by reducing our Alberta Viking, Deep Basin and standalone waterflood capital outlays by a total of $9 million.
Second Half Optionality Remains to Increase Returns and Enhance 2019 Outlook
We have the operational flexibility to adjust our capital program as Alberta commodity prices allow. We will continue to be prudent with respect to balance sheet management, and will not call on debt to fund additional development. As next quarter's pricing plays out and we get further certainty on our full year cash flow profile, we will fine tune our capital program for the second half of the year.
Financial and Operating Highlights
Three months ended December 31 |
Year ended December 31 | ||||||||||
2017 |
2016 |
% change |
2017 |
2016 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Funds Flow from Operations (1) |
$ |
52 |
$ |
48 |
8 |
$ |
192 |
$ |
182 |
5 | |
Basic per share (1) |
0.10 |
0.10 |
- |
0.38 |
0.36 |
6 | |||||
Diluted per share (1) |
0.10 |
0.10 |
- |
0.38 |
0.36 |
6 | |||||
Net loss |
(58) |
(232) |
(75) |
(84) |
(696) |
(88) | |||||
Basic per share |
(0.12) |
(0.46) |
(74) |
(0.17) |
(1.39) |
(88) | |||||
Diluted per share |
(0.12) |
(0.46) |
(74) |
(0.17) |
(1.39) |
(88) | |||||
Capital expenditures (2) |
37 |
50 |
(26) |
141 |
82 |
72 | |||||
Net Debt |
$ |
383 |
$ |
502 |
(24) |
$ |
383 |
$ |
502 |
(24) | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
14,288 |
15,803 |
(10) |
14,236 |
26,059 |
(45) | |||||
Heavy oil (bbls/d) |
5,247 |
5,493 |
(4) |
5,387 |
8,750 |
(38) | |||||
Natural gas (mmcf/d) |
71 |
103 |
(31) |
73 |
121 |
(40) | |||||
Total production (boe/d) (3) |
31,447 |
38,481 |
(18) |
31,723 |
54,990 |
(42) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
62.70 |
$ |
52.34 |
20 |
$ |
56.84 |
$ |
43.74 |
30 | |
Heavy oil (per bbl) |
38.12 |
27.09 |
41 |
33.27 |
21.22 |
57 | |||||
Natural gas (per mcf) |
$ |
2.51 |
$ |
2.98 |
(16) |
$ |
2.81 |
$ |
2.14 |
31 | |
Netback per boe (3) |
|||||||||||
Sales price |
$ |
40.55 |
$ |
33.33 |
22 |
$ |
37.58 |
$ |
28.83 |
30 | |
Risk management gain |
- |
4.27 |
(100) |
2.02 |
5.03 |
(60) | |||||
Net sales price |
40.55 |
37.60 |
8 |
39.60 |
33.86 |
17 | |||||
Royalties |
(2.64) |
(1.26) |
>100 |
(2.57) |
(1.08) |
>100 | |||||
Operating expenses (4) |
(12.50) |
(14.05) |
(11) |
(13.40) |
(13.18) |
2 | |||||
Transportation |
(2.41) |
(1.62) |
49 |
(2.48) |
(1.72) |
44 | |||||
Netback (1) |
$ |
23.00 |
$ |
20.67 |
11 |
$ |
21.15 |
$ |
17.88 |
18 |
(1) |
The terms "funds flow from operations" and their applicable per share amounts, "netback", and "net debt" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. | |
(2) |
Includes the benefit of capital carried by partners. | |
(3) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". | |
(4) |
Includes the benefit of carried operating expenses from its partner under the Peace River Oil Partnership of $6 million or $1.89 per boe (2016 – $5 million or $1.30 per boe) for the three months ended and $21 million or $1.78 per boe (2016 – $15 million or $0.75 per boe) for the year ended on a combined basis. |
The table below outlines select metrics in our key development and legacy areas for the three months ended December 31, 2017 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended December 31, 2017 | ||||
Production |
Liquids |
Operating |
Netback | ||
Cardium |
18,190 boe/d |
64% |
$13/boe |
$28/boe | |
Deep Basin |
1,356 boe/d |
31% |
$1/boe |
$28/boe | |
Alberta Viking |
2,508 boe/d |
54% |
$11/boe |
$23/boe | |
Peace River(1) |
4,963 boe/d |
99% |
$3/boe |
$30/boe | |
Key Development Areas |
27,018 boe/d |
68% |
$12/boe |
$28/boe | |
Legacy Areas(2) |
4,429 boe/d |
25% |
$28/boe |
$(6)/boe | |
Key Development & Legacy Areas |
31,447 boe/d |
62% |
$13/boe |
$23/boe |
(1) |
Net of carried operating costs. |
(2) |
A portion of Legacy Areas are classified as Assets Held for Sale. Refer to January 31, 2018 press release for more details |
The table below provides a summary of our operated activity in the fourth quarter.
Number of Wells Q4 2017 | ||||||||
Drilled |
Completed |
On stream | ||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||
Cardium |
||||||||
Producer |
6 |
5.8 |
4 |
4.0 |
7 |
6.7 | ||
Injector |
0 |
0.0 |
5 |
4.5 |
5 |
4.5 | ||
Deep Basin |
0 |
0.0 |
0 |
0.0 |
2 |
1.7 | ||
Alberta Viking |
0 |
0.0 |
0 |
0.0 |
4 |
4.0 | ||
Peace River |
4 |
2.2 |
5 |
2.8 |
5 |
2.8 | ||
Total |
10 |
8.0 |
14 |
11.3 |
23 |
19.7 |
In the Cardium, we brought on production three PCU #9 wells and five associated injectors. In Willesden Green, we brought on our four well pad late in December but due to extreme cold weather and third party pipeline curtailment, all four wells were not running at the same time until January 3, 2018.
We brought on the final two wells of our three well Mannville program, our first foray into the Deep Basin. These three wells contributed approximately 1,300 boe per day to the quarter (net to OBE) with strong liquids yields averaging 55 bbl/mmcf (135 bbl/d per well).
The second half 2017 Peace River program is currently producing approximately 2,100 boe per day gross production (1,200 boe per day net working interest). All 12 wells were on production by mid-December 2017. Per well results are consistent with expectations and reconfirm the upside we see within the heart of our acreage.
Our second half 2017 Alberta Viking program is fully optimized and all 10 wells were on production early in the fourth quarter. The wells displayed initial rates above expectations, and the total program reached a peak rate of approximately 1,900 boe per day in the quarter. The wells averaged approximately 1,200 boe per day over the quarter.
Operational Update
Our four well pad in Willesden Green Cardium was on-stream as of January 3, 2018. IP30 for the wells averaged nearly 650 boe per day (87 percent liquids). The pad is currently producing approximately 1,200 boe per day. We expect injection support to mitigate decline rates and meaningfully enhance the ultimate recovery from the wells. Our two well pad in Willesden Green, approximately 20 kilometers east, was on stream February 20, 2018. The pad has averaged approximately 900 boe per day since the wells came on production, implying an average of 450 boe per day per well over that timeframe. We have elected to add three additional Willesden Green Cardium wells to our 2018 development plans, within close proximity to our recent program. The wells will be funded from other areas of our development program.
We have drilled six and completed four wells in Pembina, which are accompanied by six low cost injector conversions for waterflood support. We expect these wells to be on production early in the second quarter.
We recently finished drilling a two-mile Mannville (Falher) well which is expected to be on stream at the end of March. Initial pressure metrics and production tests look encouraging, and we expect the well to be highly economic due to our owned infrastructure processing advantage and high liquids content. We plan to drill another Deep Basin opportunity in the second half of 2018.
Total 2018 capital expectations for Peace River are down slightly, and we shifted to a four well program from five wells. We believe four wells with varying lateral legs and lengths can deliver the same production wedge as originally anticipated. We are currently on the third of four wells and preliminary drilling and production test results are consistent with expectations.
Our second half Alberta Viking program is highly economic, targeting structural lows to maximize light oil productivity. The program will be drilled in the third quarter.
Updated Hedging Position
We continued our active hedging program and extended our hedge book into 2019. Currently, the Company has the following crude oil hedges in place:
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 |
Q1 2019 |
Q2 2019 |
Q3 2019 | ||
WTI $USD |
$50.82 |
$50.00 |
$50.05 |
$49.78 |
$50.02 |
$56.53 |
$57.00 | |
bbl/day |
7,000 |
7,000 |
8,000 |
8,000 |
3,000 |
2,000 |
1,000 | |
WTI $CAD |
$71.03 |
$71.03 |
$71.04 |
$71.04 |
$67.88 |
$68.58 |
- | |
bbl/day |
5,000 |
5,000 |
4,000 |
4,000 |
6,000 |
4,000 |
- | |
Total |
||||||||
bbl/day |
12,000 |
12,000 |
12,000 |
12,000 |
9,000 |
6,000 |
1,000 |
Additionally, the Company has the following foreign exchange contracts in place for 2018:
Currently, the Company has the following natural gas hedges in place:
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 | |||
AECO $CAD |
$2.83 |
$2.72 |
$2.67 |
$2.67 | ||
mcf/day |
28,400 |
22,700 |
17,100 |
15,200 | ||
Ventura $USD (1) |
$2.79 |
$2.79 |
$2.79 |
$2.79 | ||
mcf/day |
7,500 |
7,500 |
7,500 |
7,500 | ||
Total |
||||||
mcf/day |
35,900 |
30,200 |
24,600 |
22,700 |
(1) |
Until the third quarter of 2020, the Company has an agreement in place to sell 15 mmcf per day at the Ventura index price less the cost of transportation from AECO. Ventura pricing in the fourth quarter averaged approximately $4.00 per mcf. Recent transportation deductions for the Company to bring product to the Ventura market have been approximately $0.55 per mcf. |
2018 Guidance Summary
Our total 2018 guidance remains unchanged:
2018 Annual Guidance | |
Production |
29,000 to 30,000 boe per day |
Production Growth Rate (1) |
5% |
Operating Costs |
$13.00 - $13.50 per boe |
General & Administrative |
$2.00 - $2.50 per boe |
(1) |
Relative to full year 2017 production, adjusted for all 2017 & 2018 A&D, of 28,000 boe per day |
Our Total Capital Expenditure Guidance remains the same, but accounts for the reallocation as noted below:
Capital Category |
# of Operated Wells |
Net Capital |
Cardium |
11 Producers |
$51 million |
Deep Basin |
2 Producers |
$7 million |
Peace River |
4 Producers |
$8 million |
Alberta Viking |
4 Producers |
$6 million |
Existing Wellbore Optimization |
>50 Projects |
$14 million |
Total Development |
21 Producers |
$86 million |
Regulatory Directive 84 Requirements |
$14 million | |
Infrastructure & Corporate Capital |
$25 million | |
Total E&D Capital Expenditures |
$125 million | |
Decommissioning Expenditures |
$10 million | |
Total Capital Expenditures |
$135 million |
Proposed Share Consolidation
Obsidian Energy will propose a consolidation of the Company's outstanding common shares at the upcoming Annual and General Meeting. Obsidian believes that a share consolidation will reduce its outstanding equity float to a level more suitable to the current size of the Company, appeal to a broader universe of investors and reinforce compliance with the New York Stock Exchange's minimum share price listing requirement. The proposed 3:1 ratio balances improved marketability for the shares, reduced transaction costs for lot trading and sufficient liquidity going forward.
Shareholders will be asked to pass a special resolution that will authorize the Board of Directors to direct the Company to amend our articles, in order to consolidate (or reverse split) the Company's issued common shares into a lesser number of issued common shares on the basis of three (3) old common shares for one (1) new common share. The Board of Directors will retain the discretion to revoke the share consolidation resolution and elect not to proceed with the filing of the articles of amendment and the implementation of the share consolidation.
A share consolidation will be subject to approval of the Toronto Stock Exchange and the New York Stock Exchange. Further information regarding the potential share consolidation and timing of the Annual and General Meeting will be included in the Company's Management Information Circular to be disseminated later this spring.
Year-End 2017 Financial Results Conference Call Details
A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) on March 7, 2018.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/wcc/r/1602755-1/F3B454234B7BA6D9E327EEC65E28F03E
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 21, 2018, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 1898936, followed by the pound (#) key.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
Certain financial measures including Funds Flow from Operations, Funds Flow from Operations per share-basic, Funds Flow from Operations per share-diluted, netback and net debt included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds Flow from Operations is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of Funds Flow from Operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Financial and Operational Highlights" above for a calculation of the Company's netbacks. Net debt includes long-term debt and includes the effects of working capital and all cash held on hand.
Calculation of Funds Flow from Operations
Year ended December 31 | |||||
(millions, except per share amounts) |
2017 |
2016 | |||
Cash flow from operating activities |
$ |
125 |
$ |
(137) | |
Change in non-cash working capital |
(5) |
97 | |||
Decommissioning expenditures |
16 |
11 | |||
Office lease settlements |
16 |
4 | |||
Monetization of foreign exchange contracts |
- |
(32) | |||
Settlements of normal course foreign exchange contracts |
(8) |
(3) | |||
Monetization of transportation commitment |
- |
(20) | |||
Realized foreign exchange loss – debt prepayments |
- |
191 | |||
Realized foreign exchange loss – debt maturities |
6 |
37 | |||
Carried operating expenses (1) |
21 |
15 | |||
Restructuring charges |
10 |
19 | |||
Other expenses(2) |
11 |
- | |||
Funds flow from operations |
$ |
192 |
$ |
182 | |
Per share – funds flow from operations |
|||||
Basic per share |
$ |
0.38 |
$ |
0.36 | |
Diluted per share |
$ |
0.38 |
$ |
0.36 |
(1) |
The effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership which came to an end in December 2017. |
(2) |
The Company settled the outstanding lawsuit it had with the United States Securities and Exchange Commission ("SEC") for US$8.5 million (CAD$11 million) during the fourth quarter of 2017 |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the MD&A and audited financial statements will be filed on our website, SEDAR and EDGAR in due course; that the success of our entire 2017 program sets us up well for 2018 and beyond and we see many reasons to be excited for the future of Obsidian Energy; that our consistent production delivery and advances our operational momentum into the first quarter of 2018; that the Company is well positioned for continuous operating cost improvement driven by a dedicated push for efficiency and our recent disposition of high cost legacy assets in the Peace River area and as a result, we expect our cost basis, excluding any carry impact to decrease year over year; that certain of our natural gas volumes will be sold into Ventura through a commitments through the fourth quarter of 2020; the changes to be made in our drilling program for 2018, expectations for when they will come on stream, possible economics, liquids weighting and how they will be funded; that we have the operational flexibility to adjust our capital program as Alberta commodity prices allow; that we will continue to be prudent with respect to balance sheet management, and will not call on debt to fund additional development; that as next quarter's pricing plays out and we get further certainty on our full year cash flow profile, we will revisit our capital program for the second half of the year; that we expect injection support to mitigate decline rates and meaningfully enhance the ultimate recovery from the wells; our hedging position for both production and foreign exchange contracts; our updated capital spending plans in 2018; expected full year production; our expected production growth rate; and expected ranges for 2018 operating costs and general and administrative costs; that the Company will propose a consolidation of the Company's outstanding common shares at the upcoming Annual and General Meeting; the Company's belief that a share consolidation will reduce its outstanding equity float to a level more suitable to the current size of the Company, appeal to a broader universe of investors and reinforce compliance with the New York Stock Exchange's minimum share price listing requirement; that the proposed 3:1 ratio balances improved marketability for the shares, reduces transaction costs for lot trading and provide sufficient liquidity going forward; that shareholders will be asked to pass a special resolution at the Annual General Meeting in connection with the share consolidation; that the Board of Directors will retain the discretion to revoke the share consolidation resolution and elect not to proceed with the filing of the articles of amendment and the implementation of the share consolidation; and that the Company will disseminate its Management Information Circular later this Spring.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, Feb. 22, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that Jay W. Thornton has been appointed as Chairman of the Obsidian Energy Board of Directors (the "Board"), effectively immediately. Mr. George Brookman, who has been the Acting Chair since August 8, 2017, will remain as a director on the Board.
"On behalf of the Board, I would like to thank Mr. George Brookman for his leadership as Acting Chair over the last several months," commented Mr. Thornton. "George stepped in after the tragic passing of our previous Chairman, Rick George, and guided the Company with energy and thoughtful diligence. I look forward to continuing to steward our base strategy while exploring all opportunities to unlock shareholder value from our significant asset base."
Mr. Thornton has served on the Board since June 26, 2013 and has over 27 years of oil and gas experience, holding various operating and corporate executive positions with Shell Canada and Suncor Energy Inc. He is currently a director of North American Energy Partners Inc. and Tervita Corporation, and was previously a director with the Canadian Association of Petroleum Producers (CAPP). He is a graduate of McMaster University with an Honours degree in Economics. He also completed the Institute of Corporate Directors (ICD) Education Program.
2017 Year-End Reserves Summary
The Company is pleased to present the results of its year-end 2017 independent reserves evaluation, prepared by Sproule Associates Limited ("Sproule").
"Our year-end 2017 reserves highlight the revitalized operational delivery of the business," commented David French, President & CEO. "2017 was the first time in five years we replaced produced reserves, and grew both our proved ("1P") and proved plus probable ("2P") volumes. It is gratifying to see the recognition of our field results by our reserve evaluator.
Our updated book reflects the low decline nature of our Cardium waterflood business, and a conservative future development profile with plenty of upside. Continued recognition of the waterflood potential in our portfolio grew our 2P liquids weighting by six percent, and we hold a robust 2P reserve life index of 12 years. Adding reserves at just over $13 per boe through 2017 demonstrates a powerful engine to reward investors. We look forward to putting our capital to work."
The financial and operating information in this press release is based on estimates and is unaudited. Some of the terms below do not have standardized meanings. Further detail can be found in the "Oil and Gas Advisory" section contained in this release. This evaluation was prepared in accordance with definitions, standards, and procedures set out in the Canadian Oil and Gas Evaluation Handbook ("COGEH") and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). Additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR, EDGAR, and posted to our website, on or about March 7, 2018. All numbers are shown prior to the impact of 2018 disposition activity unless otherwise noted.
Replaced Over 100 Percent of Produced Reserves for the First Time in Five Years
Increased conviction in inventory quality, high confidence in undeveloped book additions and efficient development activity drove strong reserve replacement across the business. We replaced 126 percent of 2017 production on a 2P reserves basis, 131 percent on a 1P reserves basis and 121 percent on a proved developed producing ("PDP") reserves basis.
Integrated Waterflood is Paying Dividends by Lowering Cardium Operated Development Costs
Cardium operated development costs were $14.12 per boe, down 24 percent from year-end 2016 and 47 percent from year-end 2015. Reserve volumes associated with waterflood recovery, over and above primary development, now sit at 8.4 mmboe. The amount of future development capital ("FDC") associated with this waterflood specific volume is approximately $94 million. As we continue to demonstrate decline performance in our base wells, we expect waterflood reserve volumes to increase without the need for additional future development capital.
Total Corporate operated development costs for 2017 were $13.27 per boe. 2P finding and development ("F&D") costs, including changes in future development capital, were $1.72 per boe. These costs reflect updates to our undeveloped book to account for low cost integrated waterflood development.
Commercial Trades Increased Liquids Weighting by Six Percent
Through the disposition of natural gas weighted production in the first quarter of 2017 and gas oil ratio suppression across our waterflood acreage, our 2P liquids weighting increased by six percent, to 67 percent total liquids. Including our 2018 legacy asset disposition, our 2P liquids weighting increased to 69 percent.
The liquids weighting in our reserve book exceeds our 2018 forecasted weighting, representing the light oil growth potential of the business through increased focus on integrated waterflood development in the Cardium.
Low Decline Rate Supports Seven Year PDP Reserve Life
Our reserve book assumes an average decline rate of 16 percent in the next three years, demonstrating the sustainable production and cash flow inherent in our Cardium waterflood business. Based on Q4 2017 production and year-end 2017 reserves adjusted for disposition activity, PDP, 1P and 2P reserve life index ("RLI") is 7 years, 8 years and 12 years, respectively.
Formal Recognition of Deep Basin Potential and Upside to Undeveloped Book
Sproule has formally recognized the potential of our Deep Basin position, with five undeveloped locations across the Mannville and Rock Creek formations. Our total undeveloped reserve book remains conservative and highly achievable, with approximately 200 total locations booked, including approximately 130 in the Cardium.
Net Asset Value ("NAV") Demonstrates Highly Confident and Fundable Upside in the Business
Despite $55 million of negative pricing impacts, 2P net present value ("NPV") 10 percent grew to $1.71 billion, relative to year-end 2016 A&D adjusted NPV10 of $1.67 billion. Our 2P NPV per share, adjusted for debt, equates to approximately $2.60 per share. Our PDP NPV per share, adjusted for debt, equates to approximately $1.50 per share.
2017 Year-End Reserves Tables
In 2017, we engaged Sproule, an independent, qualified engineering firm, to evaluate one hundred percent of our 1P and 2P reserves. Sproule conducted an independent reserves evaluation of Obsidian Energy's reserves effective December 31, 2017. This evaluation was prepared in accordance with definitions, standards, and procedures set out in COGEH and NI 51-101. The Sproule reserves evaluation was based on Sproule's December 31, 2017 forecast prices and costs. Reserves included below are Company gross reserves which are the Company's total working interest reserves before the deduction of any royalties and excluding any royalty interests payable to the Company. The numbers in the tables below may not add due to rounding.
Summary of Reserves
As at December 31, 2017 |
|||||
Reserve |
Light & |
Heavy |
Natural Gas |
Conventional |
Barrel of Oil |
Estimates Category |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) |
Proved |
|||||
Developed producing |
35 |
6 |
6 |
162 |
75 |
Developed non-producing |
0 |
0 |
0 |
2 |
1 |
Undeveloped |
12 |
2 |
1 |
30 |
20 |
Total Proved |
47 |
8 |
8 |
194 |
96 |
Total Probable |
19 |
3 |
3 |
64 |
35 |
Total Proved plus Probable |
66 |
12 |
10 |
258 |
131 |
Reserves Reconciliation – Proved
Light & |
Heavy |
Natural Gas |
Conventional |
Barrel of Oil | |
Reconciliation Category |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) |
Total Proved |
|||||
December 31, 2016 |
54 |
10 |
7 |
278 |
117 |
2017 Acquisition Activity |
0 |
0 |
0 |
0 |
0 |
2017 Disposition Activity |
(8) |
0 |
(2) |
(89) |
(25) |
December 31, 2016 Adjusted for A&D |
45 |
10 |
6 |
188 |
92 |
Extensions |
3 |
0 |
1 |
18 |
7 |
Discoveries |
0 |
0 |
0 |
0 |
0 |
Infill Drilling |
2 |
1 |
0 |
2 |
3 |
Improved Recovery |
0 |
0 |
0 |
0 |
0 |
Technical Revisions |
2 |
(1) |
2 |
15 |
5 |
Economic Factors |
0 |
0 |
(0) |
(2) |
(0) |
Production |
(4) |
(2) |
(1) |
(26) |
(12) |
December 31, 2017 |
47 |
8 |
8 |
194 |
96 |
2018 Disposition Activity |
(1) |
0 |
(0) |
(23) |
(5) |
December 31, 2017 Adjusted for A&D |
46 |
8 |
7 |
171 |
91 |
Reserves Reconciliation – Proved Plus Probable
Light & |
Heavy |
Natural Gas |
Conventional |
Barrel of Oil | |
Reconciliation Category |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) |
Total Proved Plus Probable |
|||||
December 31, 2016 |
75 |
14 |
10 |
374 |
161 |
2017 Acquisition Activity |
0 |
0 |
0 |
0 |
0 |
2017 Disposition Activity |
(11) |
0 |
(2) |
(119) |
(33) |
December 31, 2016 Adjusted for A&D |
64 |
14 |
8 |
256 |
128 |
Extensions |
4 |
1 |
1 |
23 |
9 |
Discoveries |
0 |
0 |
0 |
0 |
0 |
Infill Drilling |
3 |
2 |
0 |
3 |
5 |
Improved Recovery |
5 |
0 |
0 |
7 |
6 |
Technical Revisions |
(4) |
(3) |
2 |
(2) |
(6) |
Economic Factors |
0 |
0 |
(0) |
(2) |
(0) |
Production |
(4) |
(2) |
(1) |
(26) |
(12) |
December 31, 2017 |
66 |
12 |
10 |
258 |
131 |
2018 Disposition Activity |
(1) |
0 |
(0) |
(31) |
(7) |
December 31, 2017 Adjusted for A&D |
65 |
12 |
10 |
227 |
124 |
Summary of Before Tax Net Present Values
As at December 31, 2017 |
|||||
Net Present Value |
Discount Rate | ||||
$ millions |
Undiscounted |
5 Percent |
10 Percent |
15 Percent |
20 Percent |
Proved |
|||||
Developed producing |
2,203 |
1,534 |
1,178 |
962 |
818 |
Developed non-producing |
12 |
10 |
9 |
7 |
6 |
Undeveloped |
473 |
216 |
99 |
39 |
4 |
Total Proved |
2,689 |
1,761 |
1,286 |
1,008 |
828 |
Total Probable |
1,488 |
701 |
421 |
291 |
217 |
Total Proved plus Probable |
4,176 |
2,461 |
1,707 |
1,299 |
1,046 |
Future Development Capital ("FDC")
As at December 31, 2017 |
||
Future Development Capital |
||
$ millions |
Total Proved |
Total Proved |
2018 |
74 |
91 |
2019 |
114 |
138 |
2020 |
79 |
98 |
2021 |
102 |
121 |
2022 |
87 |
112 |
2023 and subsequent |
0 |
0 |
Total, Undiscounted |
457 |
560 |
Total, Discounted @ 10% |
359 |
440 |
Summary of Pricing and Inflation Rate Assumptions
Canadian Light |
Natural Gas |
||||||||||||||
WTI |
Sweet Crude |
AECO-C |
Exchange | ||||||||||||
As at December 31, 2017 (1) |
Cushing, Oklahoma |
40° API |
Spot |
Rate | |||||||||||
Sproule Forecast |
($US/bbl) |
($Cdn/bbl) |
($Cdn/MMbtu) |
($US/$Cdn) | |||||||||||
Year |
2017 |
2016 |
2017 |
2016 |
2017 |
2016 |
2017 |
2016 | |||||||
Forecast |
|||||||||||||||
2018 |
55.00 |
65.00 |
65.44 |
74.51 |
2.85 |
3.27 |
0.79 |
0.82 | |||||||
2019 |
65.00 |
70.00 |
74.51 |
78.24 |
3.11 |
3.22 |
0.82 |
0.85 | |||||||
2020 |
70.00 |
71.40 |
78.24 |
80.64 |
3.65 |
3.91 |
0.85 |
0.85 | |||||||
2021 |
73.00 |
72.83 |
82.45 |
82.25 |
3.80 |
4.00 |
0.85 |
0.85 | |||||||
2022 |
74.46 |
74.28 |
84.10 |
83.90 |
3.95 |
4.10 |
0.85 |
0.85 | |||||||
2023 |
75.95 |
75.77 |
85.78 |
85.58 |
4.05 |
4.19 |
0.85 |
0.85 | |||||||
2024 |
77.47 |
77.29 |
87.49 |
87.29 |
4.15 |
4.29 |
0.85 |
0.85 | |||||||
2025 |
79.02 |
78.83 |
89.24 |
89.03 |
4.25 |
4.40 |
0.85 |
0.85 | |||||||
2026 |
80.60 |
80.41 |
91.03 |
90.81 |
4.36 |
4.50 |
0.85 |
0.85 | |||||||
2027 |
82.21 |
82.02 |
92.85 |
92.63 |
4.46 |
4.61 |
0.85 |
0.85 | |||||||
2028 |
83.85 |
94.71 |
4.57 |
0.85 |
|||||||||||
(1) |
Prices Escalate at two percent after 2028, with the exception of foreign exchange which stays flat |
Year-End 2017 Financial Results Conference Call Details
Obsidian Energy plans to release its financial results for the year ended December 31, 2017 before markets open on Wednesday, March 7, 2018. A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) that morning.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/wcc/r/1602755-1/F3B454234B7BA6D9E327EEC65E28F03E
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 21, 2018, 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 1898936, followed by the pound (#) key.
Oil and Gas Advisory
This press release contains a number of oil and gas metrics, including "FDC", "F&D costs", "Operated Development Costs", "NAV", and "RLI" which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods. FDC is the sum of all booked capital. F&D costs are the sum of exploration and development costs incurred in the period, plus the change in estimated FDC for the reserves category, all divided by the change in reserves during the period. F&D costs exclude the impact of acquisitions and divestitures. Operated Development Costs are the sum of drill, complete, equip, and tie-in costs to bring operated wells spud in the period on production, divided by the reserves added from these wells. NPV per share, adjusted for debt, is synonymous for NAV, and is based on the present value of future net revenues discounted at 10% before tax, adjusted for unaudited net debt as at December 31, 2017. The NPV per share is divided by the number of Obsidian Energy shares outstanding as at December 31, 2017. Reserves life index is calculated as total Company gross reserves divided by unaudited fourth quarter 2017 production.
Under NI 51-101, proved reserves estimates are defined as having a high degree of certainty to be recoverable with a targeted 90 percent probability in aggregate that actual reserves recovered over time will equal or exceed proved reserve estimates. For proved plus probable reserves under NI 51-101, the targeted probability is an equal (50 percent) likelihood that the actual reserves to be recovered will be greater or less than the proved plus probable reserve estimate. The reserve estimates set forth below are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein.
Abbreviations Contained in the Press Release
Oil and Natural Gas Liquids |
Natural Gas | |||
bbl |
barrel or barrels |
GJ |
gigajoule | |
bbl/d |
barrels per day |
GJ/d |
gigajoules per day | |
mbbl |
thousand barrels |
mcf |
thousand cubic feet | |
mmbbl |
million barrels |
mmcf |
million cubic feet | |
NGLs |
natural gas liquids |
bcf |
billion cubic feet | |
mmboe |
million barrels of oil equivalent |
mcf/d |
thousand cubic feet per day | |
mboe |
thousand barrels of oil equivalent |
mmcf/d |
million cubic feet per day | |
boe/d |
barrels of oil equivalent per day |
m3 |
cubic metres | |
mmbtu |
million British thermal units | |||
Other |
||||
AECO |
the Alberta benchmark price for natural gas. | |||
BOE or |
barrel of oil equivalent, using the conversion factor of 6 Mcf of natural gas being equivalent to one barrel of oil. | |||
WTI |
West Texas Intermediate, the reference price paid in United States dollars at Cushing, Oklahoma for crude oil of standard grade. | |||
API |
American Petroleum Institute. | |||
°API |
the measure of the density or gravity of liquid petroleum products derived from a specific gravity. | |||
MM$ |
million dollars. | |||
Forward Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that our updated reserve book reflects the low decline nature of our Cardium waterflood business, and a conservative future development profile with plenty of upside; that we hold a robust 2P reserve life index; that our reserve additions at certain costs through 2017 demonstrate a powerful engine to reward investors and that we look forward to putting our capital to work; that additional reserve information, as required under NI 51-101, will be included in our Annual Information Form which will be filed on SEDAR, EDGAR and our website on or about March 7, 2018; our expectations for FDC and as we continue to demonstrate decline performance in our base wells, and that we expect waterflood reserves volumes to increase without the need for additional development capital; that our liquids weighting of our reserve book exceeds our forecast which demonstrates the light oil growth potential of the business through increased focus on integrated waterflood development in the Cardium; the average decline rate for the next three years in our reserve book which demonstrate the sustainable production and cash flow inherent in our Cardium waterflood business; our expected RLIs; and that our total undeveloped reserve book remains conservative and highly achievable.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE". All figures are in Canadian dollars unless otherwise stated.
SOURCE Obsidian Energy Ltd.
CALGARY, Jan. 31, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that we closed an agreement to dispose of a significant portion of our non-core legacy assets, in exchange for the assumption of abandonment and reclamation liabilities.
David French, President & CEO commented, "This transaction is another important step forward for Obsidian Energy. It demonstrates the continued refocusing of the business only on assets where we can deliver distinctive performance. Our team has been working many months to close this deal, and when coupled with the solid momentum of our 2017 production results, we are off to a running start for 2018. Moving these legacy assets out of the portfolio reduces our cost structure and provides even greater financial flexibility for our second half capital program and beyond."
Legacy Asset Transaction Streamlines Operations and Improves Corporate Metrics
This legacy asset transaction demonstrates our commitment to maximizing value on behalf of all shareholders. It reduces our discounted decommissioning liabilities by approximately $25 million, improves 2018 netbacks by approximately $1.50/boe and increases our corporate liquids weighting to approximately 65 percent. The transaction is accretive to Funds Flow from Operations due to significant operating cost savings and high natural gas weighted production.
Key 2017 metrics associated with the assets are as follows(1):
Production |
2,200 boe/d |
Liquids Weighting |
25% |
Operating Cost |
$25/boe |
Field Netback (loss) |
($4)/boe |
Wellbores(2) |
650 |
Decommissioning Liability(3) |
$25MM |
(1) |
2017 figures are preliminary |
(2) |
Includes producing, non-producing and suspended wells |
(3) |
Inflated, discounted future reclamation and abandonment costs that are expected to be incurred over the life of the properties |
The transaction is subject to standard regulatory approvals such as license transfers.
2018 Guidance Update
We are revising our full year production and operating cost guidance to reflect the impact of the disposition, assuming a January 31, 2018 closing date:
2018 Annual Guidance | |
Production |
29,000 to 30,000 boe per day |
Production Growth Rate (1) |
5% |
Operating Costs |
$13.00 - $13.50 per boe |
General & Administrative |
$2.00 - $2.50 per boe |
(1) Relative to full year 2017 production, adjusted for all 2017 & 2018 A&D, of 28,000 boe per day |
Non-GAAP Measures
Fund Flow from Operations, included in this press release, does not have a standardized meaning prescribed by IFRS and therefore is considered non-GAAP measures; accordingly, it may not be comparable to similar measures provided by other issuers. Funds Flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/pre-payments and is representative of cash related to continuing operations. Funds Flow from Operations is used to assess the Company's ability to fund its planned capital programs.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that this transaction along with the solid momentum of our 2017 production results creates a clearer line of sight to the potential of 2018; moving the legacy assets out of our portfolio consolidates resources on our 2018 development plans and provides additional flexibility for the second half capital program; the expected impact to corporate metrics and being accretive to Funds Flow from Operations due to significant operating cost savings and high natural gas weighted production; our updated expected full year production; our expected production growth rate; and expected ranges for 2018 operating costs and general and administrative costs.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE". All figures are in Canadian dollars unless otherwise stated.
SOURCE Obsidian Energy Ltd.
CALGARY, Jan. 17, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") confirms it is aware of a statement by FrontFour Capital Group LLC ("FrontFour") regarding their views on the direction of the Company.
Obsidian Energy's corporate strategy is well defined and has the unanimous support of the Board of Directors (the"Board"). We have been organically growing the Company through the combination of sustaining a low decline production base and leveraging significant development optionality. The Company delivered strong results throughout the past year, and provided an operational update earlier this week that confirms the business plan is working. Those operational successes, along with our highly capital efficient 2018 plans, are a product of robust capital planning and a project review process with both Management and the Board. A change of course would hinder Obsidian Energy's progress and ability to deliver on the value maximizing efforts already underway.
As part of our active and ongoing communications with all stakeholders, Obsidian Energy's Board and Management appreciate constructive shareholder input and take all views seriously. We received a letter from FrontFour in early October, which contained ideas we had already been pursuing for several months. In addition, we received a second letter from FrontFour in mid-December threatening "more aggressive public action", unless we agreed to the addition of a mutually agreed upon Director to the Board.
In the interest of avoiding a costly and distracting proxy fight and as part of the Board's ongoing renewal process, our Board expressed a willingness to work with FrontFour regarding their views on Board composition. FrontFour had previously introduced the idea of Mr. Gordon Ritchie as a Board member, a suggestion our Board unanimously embraced due to the experience and credibility of Mr. Ritchie. Mr. Ritchie was appointed to the Board in December.
Concurrently, the Board interviewed candidates proposed by FrontFour and mutually agreed to the addition of one of those individuals. The appointment was accompanied with the same standstill agreement executed by our latest Board addition, Mr. Edward (Ed) H. Kernaghan. Despite extensive negotiations, FrontFour was unwilling to execute the agreement. As a result, we were unable to add the mutually agreed upon candidate to the Board.
One of the primary roles of our Board is to represent the interests of all shareholders. As indicated by our recent appointment of Mr. Kernaghan, our largest shareholder, we are supportive of ownership representation on the Board. Obsidian Energy's Board is now comprised of nine highly qualified and experienced directors, eight of whom are independent, including the Acting Chair. As part of our ongoing Board and governance process, the Governance Committee will nominate directors in advance of the Annual General Meeting that it believes will serve in the best interests of all shareholders.
We look forward to continuing to deliver strong results on behalf of shareholders.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE".
OBSIDIAN ENERGY: Suite 200, 207 - 9th Avenue SW, Calgary, Alberta T2P 1K3, Phone: 403-777-2500, Fax: 403-777-2699, Toll Free: 1-866-693-2707, Website: www.obsidianenergy.com; Investor Relations: Toll Free: 1-888-770-2633, E-mail: investor_relations@obsidianenergy.com
KINGSDALE ADVISORS: Ian Robertson, Executive Vice President, Communication Strategy. Direct: 416-867-2333, Cell: 647-621-2646, E-mail: irobertson@kingsdaleadvisors.com
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we will have highly capital efficient 2018 plans due to robust capital planning and a project review process with both management and the Board; that a change of course would hinder Obsidian Energy's progress and ability to deliver on the value maximizing efforts already underway; that the Governance Committee will nominate directors in advance of the annual general meeting that it believes will serve in the best interests of all shareholders; and that we look forward to continuing to deliver results on behalf of all shareholders.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
GREENWICH, Conn., Jan. 17, 2018 /PRNewswire/ -- FrontFour Capital Group LLC together with its affiliates ("FrontFour") today commented on recent developments related to Obsidian Energy Ltd. ("Obsidian" or the "Company") (TSX/NYSE: OBE). FrontFour and its principals are significant long-term shareholders of Obsidian, collectively beneficially owning over 28 million outstanding shares, representing approximately 5.7% of Obsidian's outstanding capital.
As previously disclosed in its Schedule 13D filing of November 20, 2017, on October 5, 2017, after significant dialogue with Obsidian CEO David French on the Company's development plan within the Willesden Green Cardium, as well as with numerous Obsidian directors in reaction to Obsidian's analyst day presentation and SEC lawsuit, FrontFour sent to the board of directors (the "Board") of Obsidian a letter outlining its significant concerns with Obsidian's capital plan, strategic direction and value proposition to investors. FrontFour's specific concerns included but were not limited to:
(i) the belief that Obsidian's capital program was highly flawed and has negatively impacted Obsidian's current valuation due to an emphasis on an integrated waterflood approach to developing the Cardium as opposed to a shorter cycle strategy focused on more rapidly growing Obsidian's light oil production;
(ii) the decision to spend minimal capital on drilling and completing new wells in the Cardium and Viking during the first half of 2017, resulting in sequential declines in light oil production throughout the year;
(iii) Obsidian's positioning of the Peace River joint venture as a continued core focus of capital deployment post expiry of the remaining capital carry in lieu of spending capital to grow its light oil and liquids production; and
(iv) Obsidian's inability to dispose of or improve the operations within its non-core legacy gas-weighted production.
Due to these concerns and in light of our significant long-term shareholdings in Obsidian, FrontFour also requested board representation. Despite FrontFour's tireless efforts over the last three months to come to an amicable agreement with Obsidian's management team and Board on the addition to the Board of ONE mutually agreed upon independent nominee proposed by FrontFour, we have been unable to come to an agreement that would avoid a needlessly costly and distracting proxy fight. It became apparent to FrontFour during our negotiations that the Board is divided on strategy and that certain directors are entrenched, which is surprising given their aversion to share ownership and long-term track record of underperformance.
We welcomed Obsidian's January 15, 2018 press release, which featured strong primary well performance out of the bioturbated interval within the Willesden Green Cardium and an accelerated 2018 Cardium program via the reallocation of capital from vertical waterflood injectors. Both initiatives are consistent with our private suggestions to management and our dialogue with the Board. We note that the Company made no mention of this approach in their recently released 5-year capital plan, which is less than seven months old. We believe that continued shareholder engagement is necessary, especially in light of Obsidian's ill-timed hedging strategy of selling essentially ALL of its 2018 light oil production via fixed price swaps at prices of ~$52 per barrel, which has led to material mark to market losses. This decision has created additional headwinds to equity performance as Obsidian has continued to underperform its peers, who are benefitting from the recent increase in crude prices. Despite Obsidian's vast resource base, it is clear that investors are struggling to find the equity compelling relative to its peers given the Company's below average growth rate, underwater hedge program, muddled capital plan, and lack of dividend.
FrontFour believes that a significant overhaul of Obsidian is necessary, including the streamlining of the portfolio via dispositions, and the high grading of the capital program to drive robust light oil and liquids growth within Obsidian's dominant Cardium position and vast Mannville footprint. Obsidian has the potential to be a standout light oil growth player and Cardium champion through a dramatic transformation that we believe will unlock significant value for all shareholders. To this end, FrontFour is currently considering all available options, including seeking changes to the composition of the Board at Obsidian's 2018 Annual Meeting.
FRONTFOUR CAPITAL GROUP LLC
FrontFour Capital Group LLC, located in the United States at 35 Mason Street, Greenwich, CT 06830, was formed in December 2006. FrontFour Capital Group LLC is registered with the Securities & Exchange Commission as an investment adviser under the Investment Advisers Act of 1940, as amended.
The information contained in this news release does not and is not meant to constitute a solicitation of a proxy within the meaning of applicable securities laws. Obsidian shareholders are not being asked at this time to execute a proxy in favour of any matter. Notwithstanding the foregoing, FrontFour is voluntarily providing the disclosure required under section 9.2(4) of National Instrument 51-102 – Continuous Disclosure Obligations in accordance with securities laws applicable to public broadcast solicitations. Any solicitation made by FrontFour will be made by it and not by or on behalf of the management of Obsidian. All costs incurred for any solicitation will be borne by FrontFour, provided that, subject to applicable law, FrontFour may seek reimbursement from Obsidian of FrontFour's out-of-pocket expenses, including proxy solicitation expenses and legal fees, incurred in connection with any successful result at a meeting of Obsidian shareholders. Proxies may be solicited by FrontFour pursuant to an information circular sent to shareholders after which solicitations may be made by or on behalf of FrontFour by mail, telephone, fax, email or other electronic means as well as by newspaper or other media advertising, and in person by directors, officers and employees of FrontFour, who will not be specifically remunerated therefor. FrontFour may also solicit proxies in reliance upon the public broadcast exemption to the solicitation requirements under applicable Canadian corporate and securities laws, including through press releases, speeches or publications, and by any other manner permitted under applicable Canadian laws. FrontFour may engage the services of one or more agents and authorize other persons to assist in soliciting proxies on its behalf, which agents would receive customary fees for such services. Once FrontFour has commenced any solicitation of proxies, proxies may be revoked by instrument in writing by a shareholder giving the proxy or by its duly authorized officer or attorney, or in any other manner permitted by law and the articles or by-laws of Obsidian. None of FrontFour nor, to its knowledge, any of its associates or affiliates, has any material interest, direct or indirect: (i) in any transaction since the beginning of Obsidian's most recently completed financial year or in any proposed transaction that has materially affected or would materially affect Obsidian or any of its subsidiaries; or (ii) by way of beneficial ownership of securities or otherwise, in any matter proposed to be acted on by Obsidian, other than the election of directors to the board of Obsidian. Obsidian's principal office address is 200, 207 - 9th Avenue SW Calgary, Alberta T2P 1K3.
CONTACT
Investor Contact:
Stephen Loukas/David Lorber
FrontFour Capital Group LLC
35 Mason Street, 4th Floor
Greenwich, CT 06830
203-274-9050
View original content:http://www.prnewswire.com/news-releases/long-term-shareholder-frontfour-capital-expresses-concerns-regarding-obsidian-energy-ltd-300583722.html
SOURCE FrontFour Capital Group LLC
CALGARY, Jan. 15, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to confirm full year 2017 production ahead of guidance and provide an operational update, including preliminary results from our four well pad in Willesden Green.
David French, President & CEO commented, "2017 was a great year for Obsidian Energy. We repositioned the development portfolio, effectively responded to a volatile commodity and currency environment, and exited the year with clear operational momentum. There is much to be excited about as we head into 2018. To supplement this update, we added a video to our website which gives more colour to our progress and my perspective on where the business is heading in 2018 and beyond."
Second Half Program Drives Full Year 2017 Production Above Guidance
Full year 2017 production was 31,700 boe/d, above the high end of our guidance range of 30,500 – 31,500 boe/d. Ongoing waterflood and our shallow base decline, combined with solid execution of our second half development program drove the outperformance. This marks another quarter of consistent production delivery and we look forward to maintaining this momentum through 2018.
We experienced some unexpected production downtime in December due to extreme cold weather in the last half of the month. Additionally, third party pipeline curtailment delayed on-stream timing of our four well pad in Willesden Green until early 2018. These wells are now on production and are exhibiting strong initial results as noted below.
Q4 2017 production was 31,400 boe/d, with an estimated liquids weighting of 62%. To date in January, corporate production has averaged over 32,000 boe/d despite continued cold weather related downtime.
Increased Willesden Green Cardium Production by Over 30% with New Four Well Pad
Our four well pad in Willesden Green Cardium was on-stream as of January 3, 2018. The pad has averaged approximately 2,800 boe/d since the wells came on production, implying an average of 700 boe/d per well over that timeframe. As a result, we expect to increase our entire Willesden Green Cardium production by over 30% for the month of January. These strong well results continue our successful approach to optimizing wellbore placement in the bioturbated interval and proven completion design.
Accelerated 2018 Cardium Program into December to Optimize Rig Schedule and Bring Forward Volumes
With continued execution success and a focus on capital efficiency, we decided to accelerate a portion of our 2018 capital program into 2017. In December, we drilled two primary horizontal wells in Willesden Green targeting the bioturbated interval. We also drilled three of four horizontal producers from our PCU #9 pad, which employs a low capital, integrated waterflood approach to mitigate declines. Accelerating these projects into 2017 maintained our operational efficiency which will reduce well costs and save approximately $0.5MM on the Cardium program.
Willesden Green primary wells are expected to be on production by mid-February, while the PCU #9 pad is expected to come on early April. We offset the capital cost of bringing these wells forward by delaying vertical injectors associated with our 2017 program into 2018.
Any incremental capital available in the second half of the year will likely go towards Cardium development.
Confirmed the Upside within the Heart of our Peace River Acreage
Second half execution of our 12 well Peace River program was very strong, with three of our wells exhibiting rates over 500 bbl/d per well, including December average oil production of 618 bbl/d on one of those wells. Our Peace River team continues to deliver strong results as we develop our multi-year inventory.
Some of our heavy crude oil in Peace River is priced off Western Canadian Select (WCS), which has recently muted some of the upside of higher US$ WTI pricing. To mitigate the impact of wider WCS differentials, we utilize a portfolio of sales and pricing terms, including rail transportation, which reduces the price impact by approximately half. This has helped reconfirm the attractive economics of our 2018 Peace River program and we plan to begin this program in the coming weeks.
We look forward to updating the investment community with our full 2017 financial and operating results in early March. A short video featuring David French, President & CEO, can be found under the Presentations & Events section of our website or by using the following link:
https://www.obsidianenergy.com/investor-centre/presentations-events/
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements"). Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that there is lots of be excited about as we head into 2018; that any incremental capital available in the second half of the year will likely go towards Cardium development; that we can mitigate the impact of wider WCS differentials through a portfolio of sales and pricing terms to reduce the cost impact; that we plan to begin the 2018 Peace River program due to the reconfirmed attractive economics in the coming weeks; that we look forward to maintaining the momentum of consistent production delivery through 2018; the expected increase in production for January in the Willesden Green Cardium; that accelerating certain projects will reduce well costs and save the Cardium program money; when production will come online for certain pads; and that we will update the investment community with full 2017 financial and operational results in early March.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Obsidian Energy shares are listed on both the Toronto Stock Exchange and New York Stock Exchange under the symbol "OBE". All figures are in Canadian dollars unless otherwise stated.
SOURCE Obsidian Energy Ltd.
CALGARY, Jan. 3, 2018 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that Mr. Edward (Ed) H. Kernaghan has been appointed to the Obsidian Energy Board of Directors (the "Board").
George Brookman, Obsidian Energy's Acting Chairman of the Board commented, "We are happy to have Ed Kernaghan join our Board. Mr. Kernaghan brings broad financial and capital markets experience and represents a material ownership stake through Kernwood Limited and members of his family. Mr. Kernaghan's addition is part of our ongoing commitment to ensure the right mix of skills and experience needed to steward our existing strategy."
Mr. Kernaghan commented, "As a long-term shareholder, I am excited for what the future holds as Obsidian Energy executes its business plan and am eager to support and advise on Management and the Board's current strategy. I look forward to joining the team."
Mr. Kernaghan has over 15 years of experience in the financial services business. He held the position of Executive Vice-President at Kernaghan Securities, a firm he started along with his father, Ted Kernaghan, in 2001. He is currently a partner at Kernaghan & Partners and is President of Kernwood Limited which, together with various family members, owns over 33 million shares outstanding of the Company. Mr. Kernaghan also serves on a number of other boards of TSX listed companies. Mr. Kernaghan is a graduate of the University of Toronto with a Master of Science in Theoretical Physics, and he has a Bachelor of Science, Honors degree from Queens University.
SOURCE Obsidian Energy Ltd.
CALGARY, Dec. 12, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce that Mr. Gordon Ritchie has been appointed to the Obsidian Energy Board of Directors (the "Board").
George Brookman, Obsidian Energy's Acting Chairman of the Board commented, "We are so pleased to have Gord join our Board. Gord brings extensive financial and capital markets experience and we look forward to his contribution. Gord's addition is part of our ongoing commitment to ensure the right mix of skills and experience needed to steward our existing strategy."
"I am privileged to serve on Obsidian Energy's Board of Directors and excited to help execute the strategy set forth by Management and the Board," commented Mr. Ritchie.
Mr. Ritchie has over 37 years of experience in the financial services business where he recently retired as Vice Chairman of Royal Bank of Canada ("RBC") Capital Markets. He also served as Managing Director and Head of RBC's Global E&P Energy Group and spent six years as President and Chief Executive Officer of RBC Dominion Securities Corporation in New York. Mr. Ritchie also held the position of Co-Head of RBC's International Corporate Finance Group based in London, England.
Mr. Ritchie holds securities industry regulatory designations in Canada, the U.K., and the U.S., and served for two years as a member of the New York area Advisory Committee to the New York Stock Exchange Board of Directors. He currently serves on the board of two other public companies. Mr. Ritchie holds a Masters of Business Administration from the University of Western Ontario and a Bachelor of Economics from the University of Alberta.
SOURCE Obsidian Energy Ltd.
CALGARY, Nov. 15, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces a US$8.5 million settlement with the U.S. Securities and Exchange Commission ("SEC"), regarding the lawsuit filed by the SEC on June 28, 2017 in the U.S. District Court for the Southern District of New York. The settlement is in relation to the Company's 2014 restatement of certain financial results while it was known as Penn West Petroleum Ltd. ("Penn West").
Under the terms of the settlement, the Company, without admitting or denying any of the factual allegations in the SEC's Complaint, agreed to pay a penalty of US$8.5 million. In addition, the Company will be enjoined from future violations of certain provisions of U.S. securities legislation. Further details of the settlement and its consequences can be found in the settlement documents when they are made public, and in the U.S. securities laws. The lawsuit would continue against the former Penn West employees named in the SEC Complaint. The settlement is subject to Court approval.
David French, Obsidian Energy's President and CEO commented: "Our settlement resolves this legacy Penn West issue, and we are focused on looking forward as a new company. We appreciate the open dialogue with the SEC Staff, which led to this conclusion."
SOURCE Obsidian Energy Ltd.
CALGARY, Nov. 10, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the third quarter ended September 30, 2017 and 2018 Budget. All figures are in Canadian dollars unless otherwise stated.
David French, President & CEO commented, "I am quite proud of the Obsidian Energy team in the third quarter, successfully executing our busiest drilling campaign in years and generating quality results across our key development areas. We are excited about the outlook for the Company and determined to continue operational delivery into 2018.
Deep Basin results are liquids rich and wells are flowing strong while choked back
We are encouraged with the results of our first foray into the Deep Basin. Our three Mannville wells are producing a combined 2,000 boe per day with average liquids rates of approximately 60 bbl per mmcf. These liquid yields are substantially above expectations and improve the already attractive play economics. We look forward to further 2018 development.
The Q3 program is beating forecast and reaffirms production guidance
Second half projects in the Cardium, Alberta Viking, and Peace River are delivering strong rates and reinforcing the value of our disciplined project funding and execution. As a result of production management and new well delivery, we are forecasting full year 2017 production at the high end of our 30,500 – 31,500 boe per day guidance range.
Waterflood performance is impressive
Waterflood investment is starting to bear fruit with meaningful decline mitigation across our Cardium assets. The base decline in our total Cardium business is only five percent year to date resulting from waterflood and base optimization projects initiated in 2016.
2018 delivers five percent growth at 80 percent reinvestment
We anticipate five percent production growth in 2018 while investing only 80 percent of Funds Flow from Operations. We have the operational flexibility and drill ready prospects to deliver north of five percent by adjusting our second half program as commodity prices allow. We have clear downside protection and growth confidence through our robust hedge book. Our Board has approved a $135 million 2018 budget which leverages the primary drilling opportunity set within our portfolio. We have targeted our capital to be short cycle focused while maintaining our base decline rate through efficient, low cost waterflood management.
Our 2018 plan offers a solid and scalable liquids weighted growth profile, and the third quarter and 2018 outlook are great signs for what is ahead of us as a Company."
Financial and Operating Highlights
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
2017 |
2016 |
% change |
2017 |
2016 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Gross revenues (1,2) |
$ |
98 |
$ |
136 |
(28) |
$ |
341 |
$ |
576 |
(41) | |
Funds flow from operations (2) |
40 |
32 |
25 |
140 |
134 |
4 | |||||
Basic per share (2) |
0.08 |
0.06 |
33 |
0.28 |
0.27 |
4 | |||||
Diluted per share (2) |
0.08 |
0.06 |
33 |
0.28 |
0.27 |
4 | |||||
Net loss |
(44) |
(232) |
(81) |
(26) |
(464) |
(94) | |||||
Basic per share |
(0.09) |
(0.46) |
(80) |
(0.05) |
(0.92) |
(95) | |||||
Diluted per share |
(0.09) |
(0.46) |
(80) |
(0.05) |
(0.92) |
(95) | |||||
Capital expenditures (3) |
55 |
13 |
>100 |
105 |
32 |
>100 | |||||
Net Debt (2,4) |
$ |
410 |
$ |
484 |
(15) |
$ |
410 |
$ |
484 |
(15) | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
13,324 |
17,644 |
(24) |
14,218 |
29,502 |
(52) | |||||
Heavy oil (bbls/d) |
5,456 |
5,711 |
(4) |
5,434 |
9,844 |
(45) | |||||
Natural gas (mmcf/d) |
68 |
107 |
(36) |
73 |
127 |
(43) | |||||
Total production (boe/d) (5) |
30,166 |
41,233 |
(27) |
31,816 |
60,533 |
(47) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
51.06 |
$ |
47.01 |
9 |
$ |
54.85 |
$ |
42.20 |
30 | |
Heavy oil (per bbl) |
30.36 |
21.67 |
40 |
31.69 |
20.12 |
58 | |||||
Natural gas (per mcf) |
$ |
2.35 |
$ |
2.46 |
(4) |
$ |
2.91 |
$ |
1.92 |
52 | |
Netback per boe (5) |
|||||||||||
Sales price |
$ |
33.37 |
$ |
29.50 |
13 |
$ |
36.60 |
$ |
27.86 |
31 | |
Risk management gain |
2.24 |
5.58 |
(60) |
2.69 |
5.19 |
(48) | |||||
Net sales price |
35.61 |
35.08 |
2 |
39.29 |
33.05 |
19 | |||||
Royalties |
(2.27) |
(1.63) |
39 |
(2.54) |
(1.04) |
>100 | |||||
Operating expenses (6) |
(12.26) |
(13.40) |
(9) |
(13.70) |
(12.99) |
5 | |||||
Transportation |
(2.38) |
(1.71) |
39 |
(2.50) |
(1.74) |
44 | |||||
Netback (2) |
$ |
18.70 |
$ |
18.34 |
2 |
$ |
20.55 |
$ |
17.28 |
19 |
(1) |
Includes realized gains and losses on commodity contracts. |
(2) |
The terms "gross revenues", "funds flow from operations" and their applicable per share amounts, "netback", and "net debt" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(3) |
Includes the benefit of capital carried by partners. |
(4) |
Net debt includes long-term debt and includes the effects of working capital and all cash held on hand. |
(5) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(6) |
Includes the benefit of carried operating expenses from its partner under the Peace River Oil Partnership of $5 million or $1.79 per boe (2016 – $4 million or $1.04 per boe) for the three months ended and $15 million or $1.75 per boe (2016 – $11 million or $0.66 per boe) for the nine months ended on a combined basis. |
Production Update
Average corporate production for the third quarter was 30,166 boe per day, consistent with the second quarter of 2017.
Base production continues to exceed expectations, driven by continued waterflood response across our Cardium acreage and reliability of our base infrastructure and gathering systems. We ran a successful campaign this year to optimize existing wellbores, which has contributed nearly 800 boe per day to our base production. The Company did not encounter any meaningful production impact resulting from the third-party service restrictions in the quarter.
The table below outlines select metrics in our key development and legacy areas for the three months ended September 30, 2017 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended September 30, 2017 | |||
Production |
Liquids |
Operating |
Netback | |
Cardium |
18,876 boe/d |
64% |
$13/boe |
$20/boe |
Alberta Viking |
1,766 boe/d |
49% |
$7/boe |
$22/boe |
Peace River(1) |
4,823 boe/d |
99% |
$2/boe |
$23/boe |
Key Development Areas(2) |
25,465 boe/d |
69% |
$10/boe |
$21/boe |
Legacy Areas |
4,701 boe/d |
23% |
$22/boe |
($3)/boe |
Key Development & Legacy Area |
30,166 boe/d |
62% |
$12/boe |
$19/boe |
(1) Net of carried operating costs. | ||||
(2) Deep Basin results for the quarter were negligible, and therefore included within the Cardium metrics. |
Cardium Drilling Update
Our three well horizontal pad in PCU #9 came on production in October, and early rate indications are above type curve, currently producing nearly 200 boe per day, per well. We are currently drilling our four horizontal producers in Willesden Green and expect the pad to turn over to production prior to year-end.
We continue to see positive indications of Gas Oil Ratio ("GOR") suppression and decline mitigation in our Cardium development area. Our decline rate has shallowed to approximately five percent this year, from approximately 20 percent in 2016. The observed oil rate decline shallowing is driven by our low-cost waterflood optimization and base management projects that began in the third quarter of 2016.
Alberta Viking Drilling Update
Our 10 well Alberta Viking program continues to exceed expectations, with initial production results confirming early flowback rates. All 10 wells are on production, including the 100/2-18 well with a peak IP of 704 boe per day and producing day IP30 of 295 boe per day. We continue to evolve our development strategy in the area to enhance overall economics; including trucking clean oil through design change at our multi-well batteries and optimizing stage count to maximize capital efficiency.
Peace River Drilling Update
Our second half 2017 Peace River program returned to the heart of the Harmon Valley South field, and preliminary results of the program are encouraging. Daily total production from the first nine wells of our second half 2017 program is currently averaging approximately 190 boe per day, per well. At present, 10 of 12 second half wells are on production, and two under facility construction. Obsidian Energy set another record in the third quarter for meters drilled with a single bit and bottom hole assembly, whereby we drilled 17,278 meters of open hole for an overall cost of $76 per meter drilled.
Deep Basin Drilling Update
We successfully drilled our three well Mannville program in the third quarter, with one well on production as of September 30, 2017 and the remaining two wells by the end of October. This is the Company's first foray into our significant Deep Basin position and we designed a program that tests different Upper Mannville targets. The overall program is delivering value meaningfully ahead of expectations, driven by significant initial liquids rates and high pressure from the second and third wells in the program. While the first well encountered lower permeability and pressure than expected, our second and third wells moved to a high-pressure portion of the reservoir and have significant initial liquids rates. These wells are showing free condensate rates of 35 bbl per mmcf and overall liquids rates of 60 bbl per mmcf, more than double type curve expectations. We estimate the value uptick from the strong liquids rates will increase rates of return by approximately 20 percent. We are maximizing the liquids potential of these wells by utilizing a down-hole choke mechanism to stabilize gas rates at approximately 4,000 mcf per day. Our average working interest on these wells is 80 percent.
The table below provides a summary of our operated activity in the third quarter.
Number of Wells Q3 2017 | |||||||
Drilled |
Completed |
On production | |||||
Gross |
Net |
Gross |
Net |
Gross |
Net | ||
Cardium |
|||||||
Producer |
4 |
3.7 |
3 |
2.7 |
0 |
0.0 | |
Injector |
5 |
4.5 |
0 |
0.0 |
5 |
5.0 | |
Mannville |
3 |
2.4 |
3 |
2.4 |
1 |
0.7 | |
Alberta Viking |
6 |
6.0 |
10 |
10.0 |
6 |
6.0 | |
Peace River |
8 |
4.4 |
7 |
3.9 |
7 |
3.9 | |
Total |
26 |
21.0 |
23 |
19.0 |
19 |
15.6 |
Updated Hedging Position
We continued our active hedging program and began to extend our hedge book into the second quarter of 2019. We also took advantage of the October decline in the CAD relative to the USD and hedged approximately two thirds of our foreign exchange exposure on our 2018 USD WTI hedges.
Our liquids exposure, net of royalties, is hedged approximately 65 percent through 2018 and our natural gas exposure, net of royalties, is hedged approximately 40 percent through the end of 2018. We have expanded our 2018 hedge volumes to capitalize on recent price improvements that support a fully funded 2018 capital program.
Currently, the Company has the following crude oil hedges in place:
Q4 2017 |
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 |
Q1 2019 |
Q2 2019 | |||
WTI $USD |
- |
$50.82 |
$50.00 |
$50.05 |
$49.78 |
$50.02 |
- | ||
bbl/day |
- |
7,000 |
7,000 |
8,000 |
8,000 |
3,000 |
- | ||
WTI $CAD |
$67.70 |
$71.03 |
$71.03 |
$71.04 |
$71.04 |
$66.90 |
$67.30 | ||
bbl/day |
7,900 |
5,000 |
5,000 |
4,000 |
4,000 |
4,000 |
2,000 | ||
Total |
|||||||||
bbl/day |
7,900 |
12,000 |
12,000 |
12,000 |
12,000 |
7,000 |
2,000 |
Additionally, the Company has the following foreign exchange contracts in place for 2018:
Currently, the Company has the following natural gas hedges in place:
Q4 2017 |
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 | |||
AECO $CAD |
$3.00 |
$2.83 |
$2.72 |
$2.67 |
$2.67 | ||
mcf/day |
20,900 |
28,400 |
22,700 |
17,100 |
15,200 | ||
Ventura $USD (1) |
- |
$2.79 |
$2.79 |
$2.79 |
$2.79 | ||
mcf/day |
- |
7,500 |
7,500 |
7,500 |
7,500 | ||
Total |
|||||||
mcf/day |
20,900 |
35,900 |
30,200 |
24,600 |
22,700 |
(1) |
Until the third quarter of 2020, the Company has an agreement in place to sell 15 mmcf per day at the Ventura index price less the cost of transportation from AECO. |
Disposition Highlights Subsequent to the Third Quarter
The Company entered into an agreement in late October for the sale of our royalty interests in Eastern Alberta for $40 million. The transaction capitalizes on the premium valuation associated with royalty assets and puts us in a solid liquidity position heading into 2018. Proceeds from the transaction will be used to reduce borrowings on our syndicated credit facility and therefore has a neutral effect on 2018 Funds Flow from Operations. Key metrics associated with the assets are as follows (1):
Production |
181 boe per day |
Implied Production Multiple |
$221,000 per boe per day |
Net Operating Income (NOI) |
$2.7 million |
Implied NOI Multiple |
15x |
(1) |
Based on lease operating statements for the twelve months prior to the effective date |
This royalty interest transaction is expected to close prior to the end of 2017 and is subject to closing adjustments customary in transactions of this nature.
2017 Guidance
We remain confident in our ability to demonstrate self-funded double-digit percent growth from the fourth quarter of 2016 to the fourth quarter of 2017, adjusted for A&D, and believe production will be near the high end of our full year 2017 guidance of 30,500 – 31,500 boe per day.
2017 Annual Guidance | |
Production |
30,500 to 31,500 boe per day |
Operating Costs, net of carried expenses(1) |
$13.00 to $13.50 per boe |
E&D Capital Expenditures |
$145 million |
Decommissioning Expenditures |
$15 million |
Total Capital Expenditures |
$160 million |
(1) |
Net of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
2018 Outlook
We are excited about the outlook for the Company, which combines a predictable, low decline asset base with a robust development opportunity set. Our extensive portfolio optionality allows us to shift capital allocation in response to various commodity price scenarios and deliver a returns focused capital program entirely supported by Funds Flow from Operations.
We plan to deliver approximately five percent production growth relative to full year 2017, adjusted for 2017 A&D activity. This will be accomplished by continuing our second half 2017 momentum, drilling producing wells through the first quarter of 2018. Our 2018 program is approximately 60 percent weighted to first half of 2018 and we maintain the operational flexibility to accelerate spending based on the commodity price outlook within the year. Furthermore, our hedge position provides certainty to our cash flow outlook whereby our capital program can withstand more than a 10 percent decline in Canadian dollar realized oil and gas pricing relative to current strip prices before exceeding our Funds Flow from Operations.
Our 2018 capital investment of $135 million includes $86 million associated with development and existing wellbore optimization, $25 million of infrastructure and corporate capital, $10 million of decommissioning expenditures and $14 million of capital associated with meeting the AER Directive 84 requirements for Hydrocarbon Emission Controls and Gas Conservation in the Peace River area. We are on track to meet the AER requirements and the Company will gather, process, and sell natural gas from its Peace River operations beginning in September 2018. We do not expect a material cash flow stream from natural gas in this area.
Our 2018 plans have an increased focus on shorter cycle opportunities within our portfolio. Our development capital program is approximately 50 percent weighted to the Cardium, employing a quicker payout program that balances primary drilling with targeted low capital integrated waterflood opportunities. The remainder of our development capital program has allocations of 10-15 percent each between our Deep Basin, Alberta Viking and Peace River Assets, and an additional 15 percent to capital efficient volume optimization of existing wellbores throughout our key development areas. The projected capital efficiency of our 2018 Development capital is approximately $15,000 per boe per day, based on the 12 month forward production associated with each project.
Cardium Development
We plan to spend approximately $44 million to develop our high netback, low decline Cardium asset, drilling eight horizontal producers (gross operated wells) amongst our Pembina and Willesden Green assets. Continuing our approach from the last several years, we place our horizontal wells in the bioturbated rock just below the upper good quality reservoir to ensure we access both reserves in the cleaner intervals, as well as tapping into undrained reservoir in the lower bioturbated interval. Six of our horizontal wells are in Pembina and two are in Willesden Green.
Additionally, we expect to spend approximately $5 million on integrated waterflood and optimization opportunities. This includes supporting our Pembina drills with inexpensive conversions of low producing vertical wells to injection, rather than new drills, employing a hybrid approach between our Type I & Type IV waterflood inventory. Our Cardium budget will also allocate approximately $12 million to Non-Operated primary drilling by our working interest partners in the area, and $4 million to land consolidation opportunities and seismic data. This shorter cycle focused Cardium program limits spending on new injection while still optimizing our waterflood fields and mitigating decline on horizontal wells.
Deep Basin Development
We plan to spend approximately $11 million to continue development of our Deep Basin position in 2018. Using the learnings from our 2017 development program and targeting high pressure areas of the reservoir with strategic positions close to our operated processing facilities, we plan to drill three wells through the year. Given the negative outlook for natural gas pricing in Alberta, we have high-graded our 2018 inventory to target liquids rich locations that generate robust rates of return.
Peace River Development
The Peace River area continues to be a key development area for the Company. Designing simpler wells to mitigate risk and increasing the length of individual legs to drill faster has driven cost savings that attract capital, despite the expected JV operating and capital cost carry expiry by year-end 2017. We plan to invest approximately $8 million to drill five (2.75 net) primary cold flow wells in 2018.
Alberta Viking Development
The Company plans to invest approximately $9 million to drill six wells in our Alberta Viking development area. All six wells are close to our 10 well program from 2017, and we expect similar production results. We expect slightly enhanced economics on our 2018 program using multi well pads close to existing infrastructure and by continuing to truck clean oil which enhance netbacks by approximately $1.50/bbl.
Optimization of Existing Wellbores
We plan to spend approximately $14 million on the optimization of existing well bores within our portfolio. This capital consists of over 50 individual projects to enhance field production by reactivating or re-fracking existing wells, debottlenecking, consolidating batteries, and testing additional zone potential in old vertical wells. This is some of the most capital efficient spend in our 2018 budget, projected at less than $10,000 per boe, per day. Our 2017 optimization projects contributed volumes at approximately $6,500 per boe, per day. We do not expect the same quantum of capital to be allocated to optimization past 2018.
Summary of 2018 Guidance
2018 Annual Guidance | |
Production |
31,000 to 32,000 boe per day |
Production Growth Rate (1) |
5% |
Operating Costs |
$13.50 to $14.00 per boe |
General & Administrative |
$2.00 to $2.50 per boe |
(1) Relative to full year 2017 production, adjusted for A&D, of between 29,000 – 30,000 boe per day |
Our 2018 plans are based on full year 2018 pricing of US$55 WTI, $1.28 CAD/USD & C$2.25 AECO.
Capital Category |
# of Operated Wells |
Net Capital |
Cardium |
8 Producers |
$44 million |
Deep Basin |
3 Producers |
$11 million |
Peace River |
5 Producers |
$8 million |
Alberta Viking |
6 Producers |
$9 million |
Existing Wellbore Optimization |
>50 Projects |
$14 million |
Total Development |
22 Producers |
$86 million |
Regulatory Directive 84 Requirements |
$14 million | |
Infrastructure & Corporate Capital |
$25 million | |
Total E&D Capital Expenditures |
$125 million | |
Decommissioning Expenditures |
$10 million | |
Total Capital Expenditures |
$135 million |
Conference Call Details
A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) on Friday, November 10, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1535576/E0A4361CC5204AE7C0052F290A83ABE9
A digital recording will be available for replay two hours after the call's completion, and will remain available until November 24, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 4299386, followed by the pound (#) key.
An updated corporate presentation, the third quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on the Company's website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
Certain financial measures including funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, EBITDA, netback, gross revenues and net debt included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds flow from operations is used to assess the Company's ability to fund its planned capital programs. EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation. EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated credit facility and senior notes. See "Calculation of Funds Flow from Operations" below for a reconciliation of funds flow from operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Results of Operations – Netbacks" above for a calculation of the Company's netbacks. Gross revenue is total revenues including realized risk management gains and losses on commodity contracts and is used to assess the cash realizations on commodity sales. Net debt includes long-term debt and includes the effects of working capital and all cash held on hand.
Calculation of Funds Flow from Operations
(millions, except per share amounts) |
Three months ended September 30 |
Nine months ended September 30 | |||||||
2017 |
2016 |
2017 |
2016 | ||||||
Cash flow from operating activities |
$ |
61 |
$ |
(98) |
$ |
118 |
$ |
(93) | |
Change in non-cash working capital |
(34) |
16 |
(18) |
103 | |||||
Decommissioning expenditures |
2 |
1 |
9 |
5 | |||||
Office lease settlements |
3 |
- |
11 |
- | |||||
Monetization of foreign exchange contracts |
- |
- |
- |
(32) | |||||
Settlements of normal course foreign exchange contracts |
- |
(9) |
(8) |
(3) | |||||
Monetization of transportation commitment |
- |
- |
- |
(20) | |||||
Realized foreign exchange loss – debt prepayments |
- |
113 |
- |
113 | |||||
Realized foreign exchange loss – debt maturities |
- |
- |
4 |
36 | |||||
Carried operating expenses (1) |
5 |
4 |
15 |
11 | |||||
Restructuring charges |
3 |
5 |
9 |
14 | |||||
Funds flow from operations |
$ |
40 |
$ |
32 |
$ |
140 |
$ |
134 | |
Per share |
|||||||||
Basic per share |
$ |
0.08 |
$ |
0.06 |
$ |
0.28 |
$ |
0.27 | |
Diluted per share |
$ |
0.08 |
$ |
0.06 |
$ |
0.28 |
$ |
0.27 |
(1) |
The benefit of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our excitement about the Company outlook and our determination to continue operational delivery into 2018; our forecasted full year 2017 production at the high end of our guidance; our expected 2018 production, percentage production growth rate for 2018 and associated investment level of Funds Flow from Operations, operating and general and administration cost ranges for 2018; that we have the operational flexibility and drilling prospects to deliver greater production growth by adjusting our second half program as commodity prices allow; that we have clear downside protection and confidence in growth through our hedging program; our capital spending plans in 2018; the expectation that our gas realizations will maintain a slight premium to AECO through 2018; our expectations for 2017 operating costs and the associated target range for those costs per boe (net of carried expenses); that we remain on track to meet full year 2017 capital guidance; our expected approach to development including the area-specific asset development plans described herein; the timing of development and operational activities; the expectations for timing for certain wells to be on production; the estimated value uptick in the Deep Basin from strong liquid rates; the expected closing date of the royalty interest transaction; our confidence in our ability to demonstrate self-funded double digit percentage growth from the fourth quarter of 2016 to the fourth quarter of 2017, adjusted for A&D; that we can accomplish our production growth estimates by continuing our second half 2017 momentum, by drilling producing wells through the first quarter of 2018; our ability to meet the AER requirements for Directive 84 in the Peace River Area and the Company will gather, process, and sell natural gas from its Peace River operations beginning in September 2018; the projected capital efficiency of our 2018 development capital, based on the 12 month forward production associated with each project; our intention to high-grade our 2018 inventory to target liquids rich locations that generate robust rates of return; that we expect slightly enhanced economics on our 2018 programs using multi well pads close to existing infrastructure and by continuing to truck clean oil which enhance netbacks; and that we do not expect the same quantum of capital to be allocated to existing wellbore optimization past 2018.
The key metrics for the Company set forth in this presentation may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information contained in this presentation are based on assumptions about future events based on management's assessment of the relevant information currently available. In particular, this presentation contains projected operational and financial information for end of 2017, 2018 and beyond for the Company. The future-oriented financial information and financial outlooks contained in this presentation have been approved by management as of the date of this presentation. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: 2018 prices of US$55.00 per barrel of West Texas Intermediate light sweet oil and C$2.25 per mcf AECO gas, and a C$/US$ foreign exchange rate of $1.28; that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our security holders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, Nov. 1, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX - OBE; NYSE – OBE) ("Obsidian Energy", "we", "us", "our" or the "Company") received notification from the New York Stock Exchange (the "NYSE") that we have regained compliance with the NYSE's continued listing standard regarding the price of Obsidian Energy's common stock.
The company had received notification regarding the price deficiency on September 14, 2017. The NYSE requires that the average closing price of a listed company's common stock be no less than US$1.00 per share over a consecutive 30 trading day period and close above US$1.00 per share on the last trading day of the month to regain compliance. The Company has been notified by the NYSE that is has cured the price condition and regained compliance with all NYSE continued listing requirements as of October 31, 2017.
Obsidian Energy shares are listed on the Toronto Stock Exchange and on the New York Stock Exchange under the symbol "OBE".
SOURCE Obsidian Energy Ltd.
CALGARY, Oct. 27, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX - OBE; NYSE – OBE.BC) ("Obsidian Energy", "we", "us" or "our") plans to release its third quarter 2017 financial and operating results before North American markets open on Friday, November 10, 2017. In addition, the third quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
CONFERENCE CALL & WEBCAST DETAILS
A conference call will be held to discuss the results at 6:30 a.m. MST (8:30 a.m. EST) on Friday, November 10, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1535576/E0A4361CC5204AE7C0052F290A83ABE9
A digital recording will be available for replay two hours after the call's completion, and will remain available until November 24, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 4299386, followed by the pound (#) key.
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "OBE" and on the New York Stock Exchange under the symbol "OBE.BC".
SOURCE Obsidian Energy Ltd.
CALGARY, Sept. 15, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE - OBE) ("Obsidian Energy", "we", "us" or "our") announces that it received notification on September 14, 2017 from the New York Stock Exchange (the "NYSE") that Obsidian Energy is no longer in compliance with one of the NYSE's continued listing standards applicable to Obsidian Energy because the average closing price of Obsidian Energy's common stock was less than US$1.00 per share over a consecutive 30 trading day period. As of September 12, 2017, the average closing price of Obsidian Energy's common stock over the preceding consecutive 30 trading day period was US$0.99 per share. The issuance by the NYSE of the notification is not discretionary and is sent automatically when a listed company's stock price falls below the NYSE's minimum price listing standard.
Non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the U.S. Securities and Exchange Commission (the "SEC"), nor does it breach or cause an event of default under any of Obsidian Energy's agreements with its lenders. Obsidian Energy continues to be in compliance with the terms of all of those agreements. In addition, non-compliance with the NYSE price listing standard does not affect the continued listing and trading of Obsidian Energy's common shares on the Toronto Stock Exchange (the "TSX").
Under the NYSE's rules, Obsidian Energy can avoid delisting if, within six months from the date of the NYSE notification, its common stock has a closing price on the last trading day of any calendar month and a concurrent 30 trading day average closing price of at least US$1.00 per share. Additionally, Obsidian Energy could cure the price condition by advising the NYSE of its intention to consolidate its outstanding equity float to a level more suitable to the current size of the company, which would require Obsidian Energy to obtain shareholder approval no later than our next annual general meeting. The price condition following such a consolidation is cured if the common stock price promptly exceeds US$1.00 and remains above that level for at least the following 30 trading days.
If at the expiration of the applicable cure period Obsidian Energy has not regained compliance, or Obsidian Energy has not obtained shareholder approval by the next annual meeting to consolidate its shares outstanding, the NYSE will commence suspension and delisting procedures. Management of Obsidian Energy will actively monitor the stock price and evaluate all available options in order to regain compliance with the NYSE's price listing standard within the applicable cure period.
Obsidian Energy intends to notify the NYSE within 10 business days from the date of the NYSE notification that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period or by the next annual general meeting.
Obsidian Energy's common stock will continue to be listed and traded on the NYSE during the applicable cure period, subject to compliance with the NYSE's other continued listing standards, under the symbol "OBE", but the NYSE will assign a ".BC" indicator to the symbol to denote that Obsidian Energy is below the NYSE's price listing standard. This indicator will be removed at such time as Obsidian Energy is deemed compliant with the NYSE's price listing standard.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, that non-compliance with the NYSE's price listing standard does not affect Obsidian Energy's business operations or its reporting requirements to the SEC and does not breach or cause an event of default under any of Obsidian Energy's agreements with its lenders, Obsidian Energy's continued compliance with the terms of all of those agreements, Obsidian Energy's ability to regain compliance with the NYSE's price listing standard within the applicable cure period, that management will actively monitor the stock price and evaluate all available options in order to regain compliance with the NYSE's price listing standard within the applicable cure period, Obsidian Energy's intention to notify the NYSE within 10 business days that it intends to cure this price deficiency and return to compliance with the NYSE's price listing standard prior to the expiration of the applicable cure period, and the continued listing and trading of Obsidian Energy's common shares on the TSX.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward‑looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 9, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX/NYSE – OBE) ("Obsidian Energy", the "Company", "we", "us" or "our") announces its financial and operational results for the three months ended June 30, 2017.
"This is a quarterly release with mixed emotion," commented David French, President and Chief Executive Officer. "We have lost a dear friend and leader in the passing of Rick George, the Chairman of the Board. His guidance and courage throughout Obsidian Energy's restructuring and re-emergence was instrumental to forging our new path. He leaves us with an imprint of the highest integrity and dedication to task that we will carry forward as a new Company. We wish his family peace through their immeasurable loss.
As our first quarter formally as Obsidian Energy, we are off to a solid start. Despite limited activity in seasonal breakup conditions, we continued our operational momentum through the second quarter of 2017 to deliver strong production volumes and robust funds flow from operations.
As we look forward to our second half development program, we elected to reallocate and reduce our capital budget by $20 million to fit the current price environment yet our strong base production and early development results allow us to maintain production guidance. Company financials are stable with long term debt below $400 million, and we continue to actively extend our hedge book to underpin 2017 and 2018 development with a deep portfolio of investable projects across Alberta that work in a $45 to $55 West Texas Intermediate world.
The next several months will be very important as we embark on our most active development program in three years. We are well positioned to manage the current commodity environment and look forward to updating the market through the new lens of Obsidian Energy: disciplined, relentless, and accountable.
George Brookman, head of Obsidian Energy's Governance Committee, has assumed the role of Acting Chairman while the Board of Directors evaluates candidate options."
Obsidian Energy Results for the Three and Six Months Ended June 30, 2017
Three months ended June 30 |
Six months ended June 30 | ||||||||||
2017 |
2016 |
% change |
2017 |
2016 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Gross revenues (1) |
$ |
111 |
$ |
209 |
(47) |
$ |
243 |
$ |
440 |
(45) | |
Funds flow from operations (2) |
43 |
55 |
(22) |
100 |
102 |
(2) | |||||
Basic per share (2) |
0.09 |
0.11 |
(18) |
0.20 |
0.20 |
- | |||||
Diluted per share (2) |
0.09 |
0.11 |
(18) |
0.20 |
0.20 |
- | |||||
Net income (loss) |
(9) |
(132) |
(93) |
18 |
(232) |
>(100) | |||||
Basic per share |
(0.02) |
(0.26) |
(92) |
0.04 |
(0.46) |
>(100) | |||||
Diluted per share |
(0.02) |
(0.26) |
(92) |
0.04 |
(0.46) |
>(100) | |||||
Capital expenditures (3) |
24 |
1 |
>100 |
50 |
19 |
>100 | |||||
Long-term debt |
$ |
392 |
$ |
1,535 |
(74) |
$ |
392 |
$ |
1,535 |
(74) | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
13,396 |
30,421 |
(56) |
14,966 |
35,497 |
(58) | |||||
Heavy oil (bbls/d) |
5,636 |
11,427 |
(51) |
5,423 |
11,934 |
(55) | |||||
Natural gas (mmcf/d) |
68 |
130 |
(48) |
75 |
137 |
(45) | |||||
Total production (boe/d) (4) |
30,436 |
63,568 |
(52) |
32,655 |
70,289 |
(54) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
56.12 |
$ |
49.66 |
13 |
$ |
56.60 |
$ |
40.99 |
38 | |
Heavy oil (per bbl) |
31.61 |
25.18 |
26 |
32.37 |
19.75 |
64 | |||||
Natural gas (per mcf) |
$ |
3.10 |
$ |
1.42 |
>100 |
$ |
3.16 |
$ |
1.70 |
86 | |
Netback per boe (4) |
|||||||||||
Sales price |
$ |
37.51 |
$ |
31.20 |
20 |
$ |
38.11 |
$ |
27.38 |
39 | |
Risk management gain |
2.21 |
4.27 |
(48) |
2.91 |
5.08 |
(43) | |||||
Net sales price |
39.72 |
35.47 |
12 |
41.02 |
32.46 |
26 | |||||
Royalties |
(2.67) |
(0.63) |
>100 |
(2.68) |
(0.87) |
>100 | |||||
Operating expenses (5) |
(14.27) |
(12.70) |
12 |
(14.38) |
(12.87) |
12 | |||||
Transportation |
(2.82) |
(1.89) |
49 |
(2.55) |
(1.75) |
46 | |||||
Netback (2) |
$ |
19.96 |
$ |
20.25 |
(1) |
$ |
21.41 |
$ |
16.97 |
26 |
(1) |
Includes realized gains and losses on commodity contracts. |
(2) |
The terms "funds flow from operations" and their applicable per share amounts, and "netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(3) |
Includes the effect of capital carried from its partner under the Peace River Oil Partnership. |
(4) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(5) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $6 million or $2.17 per boe (2016 – $3 million or $0.52 per boe) for the three months ended June 30, 2017 and $10 million or $1.69 per boe (2016 – $7 million or $0.55 per boe) for the six months ended June 30, 2017. |
Second Quarter Operational and Financial Highlights
Delivering on Production and Operating Cost Guidance
Capital Realigned for the Current Price Environment
Financials are Stable and Strong
Early Development Wins are Setting a Solid Stage for 2018
Operational Metrics
Obsidian Energy holds a focused portfolio with industry leading positions in the Cardium, Peace River, and Alberta Viking areas. The table below outlines select metrics in our key development and legacy areas for the three and six months ended June 30, 2017 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended June 30, 2017 | |||
Production |
Liquids |
Operating |
Netback | |
Cardium |
18,430 boe/d |
63% |
$14/boe |
$27/boe |
Alberta Viking |
1,976 boe/d |
51% |
$12/boe |
$22/boe |
Peace River(1) |
4,928 boe/d |
99% |
<$1/boe |
$24/boe |
Key Development Areas |
25,334 boe/d |
69% |
$11/boe |
$26/boe |
Legacy Areas |
4,649 boe/d |
25% |
$27/boe |
($10)/boe |
Key Development & Legacy Areas(2) |
29,983 boe/d |
62% |
$13/boe |
$20/boe |
(1) |
Net of carried operating costs |
(2) |
Excludes the impact of properties sold during the quarter |
The table below provides a summary of our operated activity during the second quarter:
Number of Wells | ||||||||
Drilled |
Completed |
On production | ||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||
Cardium |
4 |
4 |
8 |
8 |
17 |
17 | ||
Producer |
0 |
0 |
0 |
0 |
0 |
0 | ||
Injector |
4 |
4 |
8 |
8 |
17 |
17 | ||
Alberta Viking |
4 |
4 |
0 |
0 |
0 |
0 | ||
Peace River |
5 |
3 |
5 |
3 |
5 |
3 | ||
Total |
13 |
11 |
13 |
11 |
22 |
20 |
Maintaining Production Guidance and Re-Aligning Capital Spending
We are adjusting our 2017 development plans to reduce our full-year capital budget by $20 million to $160 million. Most of the capital changes are related to projects that were intended to extend our double-digit percent growth trajectory through next year.
Capital Category |
# of Operated Wells |
Net Capital |
Cardium Waterflood Platform |
7 Producers, 26 Vertical Injectors |
$80 million |
Manufacture Cold Flow |
21 Producers, 5 Stratigraphic |
$5 million |
Optimize Volumes with Viking |
10 Producers |
$20 million |
Pursue New Ventures |
3 Producers |
$12 million |
Total Development |
41 Producers, 26 Vertical Injectors |
$117 million |
Base Capital |
$28 million | |
Total E&D Capital Expenditures |
$145 million | |
Decommissioning Expenditures |
$15 million | |
Total Capital Expenditures |
$160 million |
Due to continued high production volumes from last winter's drilling program and a strong outlook for our second half development program, we do not expect the capital reductions to have a material effect on our full-year operational results. In our second half development program, we expect the majority of our new wells will be brought on production late in the third quarter or early in the fourth quarter. We remain confident in our ability to demonstrate self-funded double-digit percent growth from the fourth quarter of 2016 to the fourth quarter of 2017 and to meet our full year 2017 production guidance of 30,500 to 31,500 boe per day.
2017 Annual Guidance | |||
Updated Guidance |
Previous Guidance |
Change | |
Production |
30,500 to 31,500 boe per day |
30,500 to 31,500 boe per day |
No Change |
Operating Costs, net of carried expenses(1) |
$13.00 to $13.50 per boe |
$13.00 to $13.50 per boe |
No Change |
E&D Capital Expenditures |
$145 million |
$160 million |
($15) |
Decommissioning Expenditures |
$15 million |
$20 million |
($5) |
Total Capital Expenditures |
$160 million |
$180 million |
($20) |
(1) |
Net of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
Updated Hedging Position
Our hedging program helps reduce the volatility of our funds flow from operations, and thereby improves our ability to manage our ongoing capital programs. We target having hedges in place for approximately 25 percent to 50 percent of our crude oil exposure, net of royalties, and 20 percent to 50 percent of our gas exposure, net of royalties. Refer to the "Financials are Stable and Strong" section for more information on our current hedging levels.
Our positions as of August 8, 2017 are as follows:
Q3 2017 |
Q4 2017 |
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 | ||
Oil Volume (bbl/d) |
7,400 |
7,900 |
8,000 |
8,000 |
5,000 |
4,000 | |
US$ WTI Price (US$/bbl) (1) |
US$51.96 |
US$52.17 |
US$51.31 |
US$50.59 |
US$49.96 |
US$49.07 | |
Gas Volume (mcf/d) |
19,000 |
20,900 |
28,400 |
22,700 |
17,100 |
15,200 | |
AECO Price (C$/mcf) |
$2.84 |
$3.00 |
$2.83 |
$2.72 |
$2.67 |
$2.67 |
(1) |
US$ price implied using foreign exchange rates as at June 30, 2017. |
Conference Call Details
A conference call will be held to discuss the second quarter results above at 6:30 am Mountain Time (8:30 am Eastern Time) on Wednesday, August 9, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1477193/2D92047EF3170543402318FDBF2EF764
A digital recording will be available for replay two hours after the call's completion, and will remain available until August 23, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 62923353, followed by the pound (#) key.
An updated corporate presentation, the second quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on the Company's website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
Certain financial measures including funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, EBITDA, netback and gross revenues included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds flow from operations is used to assess the Company's ability to fund its planned capital programs. EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. Additionally, under the syndicated credit facility, realized foreign exchange gains or losses related to debt maturities are excluded from the calculation. EBITDA as defined by Obsidian Energy's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Obsidian Energy's covenant calculations related to its syndicated credit facility and senior notes.
See "Calculation of Funds Flow from Operations" below for a reconciliation of funds flow from operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Results of Operations – Netbacks" above for a calculation of the Company's netbacks. Gross revenue is total revenues including realized risk management gains and losses on commodity contracts and is used to assess the cash realizations on commodity sales.
Calculation of Funds Flow from Operations
(millions, except per share amounts) |
Three months ended June 30 |
Six months ended June 30 | |||||||
2017 |
2016 |
2017 |
2016 | ||||||
Cash flow from operating activities |
$ |
19 |
$ |
(56) |
$ |
57 |
$ |
5 | |
Change in non-cash working capital |
14 |
61 |
16 |
87 | |||||
Decommissioning expenditures |
3 |
2 |
7 |
4 | |||||
Office lease settlements |
4 |
- |
8 |
- | |||||
Monetization of foreign exchange contracts |
- |
- |
- |
(32) | |||||
Settlements of normal course foreign exchange contracts |
(8) |
6 |
(8) |
6 | |||||
Monetization of transportation commitment |
- |
- |
- |
(20) | |||||
Realized foreign exchange loss – debt maturities |
1 |
36 |
4 |
36 | |||||
Carried operating expenses (1) |
6 |
3 |
10 |
7 | |||||
Restructuring charges |
4 |
3 |
6 |
9 | |||||
Funds flow from operations |
$ |
43 |
$ |
55 |
$ |
100 |
$ |
102 | |
Per share |
|||||||||
Basic per share |
$ |
0.09 |
$ |
0.11 |
$ |
0.20 |
$ |
0.20 | |
Diluted per share |
$ |
0.09 |
$ |
0.11 |
$ |
0.20 |
$ |
0.20 |
(1) |
The effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we are well positioned to manage the current commodity environment; our expected percentage production growth rate; our expected approach to development including the area-specific asset development plans described herein; our expectations for operating costs during the year and the associated target range for those costs per boe (net of carried expenses); our capital spending plans in 2017 and that: (i) most of the capital changes are on projects that were intended to extend our double digit growth through the next year and (ii) we do not expect the capital reductions to have a material effect on our full-year operational results; the timing of development and operational activities; the expectations for timing for certain wells to be on production; how certain gas wells will be processed which will minimize processing costs; that we remain confident in our ability to demonstrate self-funded double digit percentage growth from the fourth quarter of 2016 to the fourth quarter of 2017 and meeting our full year 2017 production guidance; and our hedging program and its ability to reduce the volatility of our funds flow from operations and thereby improves our ability to manage our ongoing capital programs.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: 2017 prices of US$54.07 per barrel of West Texas Intermediate light sweet oil and C$3.32 per mcf AECO gas, and a C$/US$ foreign exchange rate of $1.32; that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 3, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX - OBE; NYSE - OBE) ("Obsidian Energy", "we", "us" or "our") is expected to release its second quarter 2017 financial and operating results on Wednesday, August 9, 2017 before North American markets open. In addition, the second quarter management's discussion and analysis and the unaudited consolidated financial statements will be available on our website at www.obsidianenergy.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
CONFERENCE CALL & WEBCAST DETAILS
A conference call will be held to discuss the matters noted above at 6:30 am Mountain Time (8:30 am Eastern Time) on Wednesday, August 9, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1477193/2D92047EF3170543402318FDBF2EF764
A digital recording will be available for replay two hours after the call's completion, and will remain available until August 23, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 62923353, followed by the pound (#) key.
Obsidian Energy shares are listed on the Toronto Stock Exchange and on the New York Stock Exchange under the symbol "OBE".
SOURCE Obsidian Energy Ltd.
CALGARY, Aug. 2, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD. (TSX - OBE; NYSE - OBE) ("Obsidian Energy", "we", "us" or "our") regrets to announce the passing of its Chairman Rick George on August 1.
"The company and our Board of Directors want to offer our sincerest condolences and sympathy to Rick's family," said David French, President and Chief Executive Officer. "It was a privilege to know the man, and experience his leadership and devotion to our industry. Over his tenure as our Chairman, Rick reshaped our company from top to bottom. Rick's legacy will continue with the many lives he has touched."
Obsidian Energy shares are listed on the Toronto Stock Exchange and on the New York Stock Exchange under the symbol "OBE".
SOURCE Obsidian Energy Ltd.
CALGARY, June 28, 2017 /PRNewswire/ - OBSIDIAN ENERGY LTD., formerly named PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West" or "Obsidian Energy" as applicable depending on context, the "Company", "we", "us" or "our") and three of its former employees were named in a law suit filed by the U.S. Securities and Exchange Commission ("SEC") on June 28, 2017 in the U.S. District Court for the Southern District of New York.
The law suit is based on certain historic Penn West accounting practices, discovered by the Company and reported to the SEC in July 2014. As a result of the Company's discovery, investigation, and correction of those practices, Penn West restated its historic financial statements and results on September 18, 2014.
The SEC's complaint, based on those historic practices, alleges that Penn West violated statutes which include Section 10(b), 13(b), 13(b)(2)(A) and 13(b)(2)(B) of the Securities Exchange Act of 1934 and certain related rules. The complaint requests the entry of injunctive relief preventing a reoccurrence of the practices and certain financial relief.
David French, Obsidian Energy's President and CEO, commented: "We are naturally disappointed that the SEC has chosen to pursue these past matters which we reported to them and fully remediated years ago. This is particularly true since the employees involved in the matters have long since left the Company. We respect and appreciate the SEC's view of its obligations regarding these past matters and look forward to a timely resolution.
We do not anticipate this matter to materially alter the business activities of the Company. We are confident about what tomorrow holds, and the transparent and disciplined approach we have in place to guide and report our performance. For Penn West, now Obsidian Energy, the focus is on the future."
Obsidian Energy shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
Forward Looking Statements
Certain statements contained in this presentation constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. In particular, this presentation contains, without limitation, forward-looking statements pertaining to our anticipation that the lawsuit described herein will not materially alter the business activities of the Company, and our confidence about what tomorrow holds and the transparent and disciplined approach we have in place to guide and report our performance.
Additional information on factors that could affect the Company, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein)), Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com), EDGAR website (www.sec.gov) or the Company's website.
Unless otherwise specified, the forward-looking statements contained in this document speak only as of June 27, 2017. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Obsidian Energy Ltd.
CALGARY, June 26, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West" "or the Company") is pleased to announce that our shareholders have approved our name change to Obsidian Energy Ltd., effective immediately. In conjunction with our name change, our stock symbol will be replaced with "OBE" on both the Toronto Stock Exchange and New York Stock Exchange, effective in the next 3 – 5 business days. No action is required by shareholders with respect to this change.
"We are pleased to recognize the last step in our transformation with a name change to Obsidian Energy. As we start a new chapter in our story, we will guide the Company on three principles: disciplined technical and commercial decision-making to build and protect enterprise value, relentless pursuit of progress and innovation, and accountable and transparent efforts with our shareholders, our partners and the communities in which we operate. Obsidian Energy is well positioned with the right assets, a healthy balance sheet and a prudent hedging strategy that will allow the Company to set a standard for performance even in lower price environments," commented David French, President and Chief Executive Officer.
In addition to the name change, shareholders approved all resolutions outlined in the Notice of 2017 Annual and Special Meeting and Management Proxy Circular dated April 30, 2017 (the "Information Circular"), which is available on SEDAR at www.sedar.com, on EDGAR at www.sec.gov, and on the Company website at www.pennwest.com, which will in due course become www.obsidianenergy.com. See below for further details.
1. Appointment of Auditor
By resolution passed by show of hands, Ernst & Young LLP, Chartered Accountants, was appointed as auditor of Penn West for the ensuing year.
2. Election of Directors
By resolutions passed by ballot vote, the following eight nominees proposed by management were elected as directors of the Company to hold office until the next annual meeting of Shareholders or until their successors are elected or appointed:
Name of Nominee |
||||
Votes For |
Percent |
Votes Withheld |
Percent | |
George H. Brookman |
171,547,614 |
95.44% |
8,195,244 |
4.56% |
John Brydson |
172,677,487 |
96.07% |
7,065,371 |
3.93% |
Raymond D. Crossley |
173,814,934 |
96.70% |
5,927,924 |
3.30% |
David L. French |
172,488,980 |
95.96% |
7,253,878 |
4.04% |
William A. Friley |
171,035,516 |
95.16% |
8,707,342 |
4.84% |
Richard L. George |
169,110,161 |
94.08% |
10,632,697 |
5.92% |
Maureen Cormier Jackson |
170,927,882 |
95.10% |
8,814,976 |
4.90% |
Jay W. Thornton |
171,195,207 |
95.24% |
8,547,651 |
4.76% |
3. Non-Binding Advisory Vote on the Corporation's Approach to Executive Compensation
By resolution passed by ballot vote, an advisory resolution was passed to approve the Company's approach to executive compensation as outlined in the Information Circular. The results of the ballot were as follows:
Votes For |
Votes Against | ||
Number |
Percent |
Number |
Percent |
168,359,816 |
93.66% |
11,394,787 |
6.34% |
4. Approval of Amendment to Restricted Share Unit Plan
By resolution passed by ballot vote, the amendment to the restricted share unit plan to become the restricted and performance share unit plan was approved. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
169,112,614 |
94.08% |
10,641,886 |
5.92% |
5. Approval of Name Change to Obsidian Energy Ltd.
By resolution passed by ballot vote, a special resolution was approved to the amendment to the articles of Penn West to chance the name to Obsidian Energy Ltd. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
278,070,022 |
92.91% |
21,220,502 |
7.09% |
6. Approval of Reduction of Share Capital for Accounting Purposes
By resolution passed by ballot vote, the reduction of Penn West's share capital for accounting purposes was approved. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
173,395,303 |
96.46% |
6,359,201 |
3.54% |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that we will guide the Company on three principles: disciplined technical and commercial decision-making to build and protect enterprise value, relentless pursuit of progress and innovation, and accountable and transparent efforts with our shareholders, our partners and the communities that we operate; that we are well positioned with the right assets, a healthy balance sheet and a prudent hedging strategy that will allow the Company to set a standard for performance even in lower price environments.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: that we do not dispose of any material producing properties; our ability to execute our long-term plan and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior unsecured notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
About Obsidian Energy
Obsidian Energy is an intermediate-sized oil and gas producer with a well-balanced portfolio of high-quality assets based in Western Canada. Obsidian Energy is a company based on discipline, relentless passion for the work we do, and resolute accountability to our shareholders, our partners and the communities in which we operate.
SOURCE Penn West
CALGARY, June 22, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", the "Company", "we", "us" or "our") is hosting its Annual and Special Meeting on Monday, June 26, 2017, beginning at 10:00 am Mountain Time (12:00 pm Eastern Time) at the Metropolitan Conference Centre, located at 333 – 4th Avenue SW, Calgary Alberta.
Scheduled as part of the meeting proceedings, Mr. David French, President and CEO, will address shareholders and provide a brief presentation on the Company. This address will be available on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1453477/7D919FE174BB03DA74BADBD823036491
A replay of the audio webcast will be available for replay one hour after the conclusion of the presentation on our website www.pennwest.com.
Electronic copies of our management proxy circular, financial statements, news releases, and other public information are available on our website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, June 5, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is hosting an Analyst Day event on Wednesday, June 7, 2017, beginning at 1:00 pm Mountain Time (3:00 pm Eastern Time) to offer the investment community a comprehensive technical overview of our cost structure, operations, and sustainable growth strategy. The event will be held in Calgary for members of the financial analyst community and simultaneously webcast for the public and those unable to attend in person.
CONFERENCE CALL & WEBCAST DETAILS
A live broadcast of the Analyst Day presentation will be available on the Internet and may be accessed directly at the following URL:
https://event.on24.com/wcc/r/1436098/9FBBF2030CF35B1E1C440003A08CD207
A recording of the Analyst Day presentation will be available for replay one hour after the conclusion of the presentation on our website www.pennwest.com, or directly at above URL.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, May 26, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West", the "Company", "we", "us" or "our") is pleased to propose a name change to Obsidian Energy Ltd.
"As we look around today, our Company is very different from just a few short years ago," reflected David French, President and Chief Executive Officer. "Over the past several months, we spoke a lot about concluding the story of our restructuring, which touched everything from our balance sheet, key development areas, people and operating practices. We rebuilt the Company from the assets up and refocused from the top down.
We no longer resemble the old 'Penn West'. This year marks a new beginning for us, and we are excited to turn the page on a new chapter. In recognition of this, we will ask our shareholders to vote in favour of a proposed name change at our upcoming Annual and Special Meeting — a name and set of principles that will guide us as we move forward. Our new company is one based on discipline, relentless passion for the work we do, and accountability to our shareholders, our partners and the communities in which we operate.
We propose the name 'Obsidian Energy', after a naturally occurring volcanic glass with a similar sheen to crude oil. Obsidian is created through a geological process transforming into a substance of strength, dependability, and longevity. We'll be proud to take the name and what it means for us.
As a Company, we are positioned with the right assets, people, and organizational structure to succeed in the current commodity price environment. We look forward to providing a more detailed review of our portfolio at our Analyst Day in the coming weeks and to our upcoming Annual and Special Meeting."
Corporate Presentation
For those interested in learning more about the proposed name change, the Company has uploaded a brief presentation and video to its website, www.pennwest.com.
Annual and Special Meeting
WHEN: |
Monday, June 26, 2017, at 10:00 a.m. (Mountain Daylight Time) |
WHERE: |
Metropolitan Conference Centre |
333 – 4th Avenue SW | |
Calgary, Alberta |
Associated Meeting Materials
Shareholders are reminded to review the management information circular (the "Circular") prior to voting as the Circular has been prepared to help you make an informed decision.
The meeting materials (including the Circular) can be viewed online through the Company's website www.pennwest.com, its profile on www.sedar.com or www.sec.gov and at the following internet address: www.meetingdocuments.com/cst/pwt.
You can also call our proxy solicitation agent, Kingsdale Advisors, at 1-800-775-1986 (toll-free within North America) or 416-867-2272 (collect call outside North America) if you have any questions or concerns.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: asking shareholders to approve the proposed name change at the scheduled Annual and Special Meeting of the Company; that the new name and set of principles will guide us as we move forward; that we will be proud to take the name and what it means for us; that we are positioned with the right assets, people and organizational structure to succeed in the current commodity price environment; and that at the analyst day in the coming weeks and at the upcoming Annual and Special Meeting, we will give the public a more detailed review of our portfolio.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: the Annual and Special Meeting will occur on the scheduled day or within the allowable time frame for a postponement of adjournment; that the analyst day will occur in the coming weeks; that the shareholders will approve the name change and the Company can proceed as Obsidian Energy; and that we will continue to have the same assets, people and organizational structure moving forward in this pricing environment.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, March 15, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") announces that it has filed with Canadian securities regulatory authorities its audited Consolidated Financial Statements for the year ended December 31, 2016 and related Management's Discussion and Analysis. Penn West has also filed its Annual Information Form for the year ended December 31, 2016, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101. Penn West's Annual Report on Form 40-F for the year ended December 31, 2016 will be filed with the U.S. Securities and Exchange Commission pursuant to its rules and regulations.
Copies of these documents may be obtained electronically via www.sedar.com and www.sec.gov/edgar.shtml (for the Form 40-F) or through Penn West's website at www.pennwest.com. Hard copies of Penn West's audited Consolidated Financial Statements and related MD&A are also available upon request, free of charge, by contacting our Investor Relations group or by requesting them through our website.
Penn West shares are listed on the Toronto Stock Exchange under the symbol" PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, March 15, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce financial and operational results for the year ended December 31, 2016, along with year-end 2016 reserves results.
"2016 was a year of reshaping and rebuilding for Penn West as we examined every aspect of our business to ensure we are well structured to thrive in today's commodity price environment," commented David French, President and Chief Executive Officer.
"Throughout 2016 we focused our efforts on three things. First, we simplified our balance sheet by completing our disposition program resulting in $1.4 billion in asset-sales in 2016, with an additional $65 million closed to date in the first quarter and a final $10 million to be completed shortly. These sales allowed us to reduce our debt by 76% in 2016 and significantly lower environmental liabilities, putting us on track to bring our Alberta Liability Management Ratio ("LMR") to two times by the end of 2017.
Second, we refocused our attention on operational efficiencies in a small number of key development areas where we hold industry leading positions. These changes are already bearing fruit, exhibited by a 12% increase in our cash margins, inclusive of hedging, year over year. Our portfolio offers an attractive balance of shorter-cycle opportunities including industry leading well rates in the Alberta Viking and cold flow manufacturing in Peace River, complemented by our mid-cycle Cardium integrated waterflood development. Our production mix is liquids-weighted and can be toggled higher or lower as we see fit. We are working the right assets and delivering their promise.
And lastly, we reshaped our year-end reserves to reflect a simpler and cleaner Penn West. We received our first foothold reserve bookings for early results in our Cardium waterflood program, saw proceeds from sales from our divestment program exceed the change in our net asset value, and realigned our reserves in Peace River to shift from thermal to cold flow development. Our year-end results and reserves reflect the substantial underlying value of our new portfolio and provide a platform well positioned for growth and cash flow generation for years to come.
As we close the chapter on 2016, 2017 offers investors and stakeholders a platform focused on long-term value creation. The foundation of our portfolio of assets is best defined as leading positions in key development areas that will offer double-digit organic and self-funded growth in production over the course of 2017."
Penn West Results for the Three and Twelve Months Ended December 31, 2016
Three months ended December 31 |
Twelve months ended December 31 | ||||||||||
2016 |
2015 |
% change |
2016 |
2015 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Funds flow from operations (1) |
$ |
48 |
$ |
39 |
23 |
$ |
182 |
$ |
249 |
(27) | |
Basic per share (1) |
0.10 |
0.08 |
25 |
0.36 |
0.50 |
(28) | |||||
Diluted per share (1) |
0.10 |
0.08 |
25 |
0.36 |
0.50 |
(28) | |||||
Net loss |
(232) |
(1,606) |
(86) |
(696) |
(2,646) |
(74) | |||||
Basic per share |
(0.46) |
(3.20) |
(86) |
(1.39) |
(5.27) |
(74) | |||||
Diluted per share |
(0.46) |
(3.20) |
(86) |
(1.39) |
(5.27) |
(74) | |||||
Capital expenditures (2) |
50 |
99 |
(49) |
82 |
470 |
(83) | |||||
Long-term Debt |
$ |
469 |
$ |
1,940 |
(76) |
$ |
469 |
$ |
1,940 |
(76) | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
15,803 |
41,378 |
(62) |
26,059 |
47,279 |
(45) | |||||
Heavy oil (bbls/d) |
5,493 |
11,962 |
(54) |
8,750 |
11,984 |
(27) | |||||
Natural gas (mmcf/d) |
103 |
144 |
(28) |
121 |
163 |
(26) | |||||
Total production (boe/d) (3) |
38,481 |
77,398 |
(50) |
54,990 |
86,357 |
(36) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
52.34 |
$ |
47.00 |
11 |
$ |
43.74 |
$ |
50.05 |
(13) | |
Heavy oil (per bbl) |
27.09 |
25.40 |
7 |
21.22 |
33.26 |
(36) | |||||
Natural gas (per mcf) |
$ |
2.98 |
$ |
2.54 |
17 |
$ |
2.14 |
$ |
2.86 |
(25) | |
Netback per boe (3) |
|||||||||||
Sales price |
$ |
33.33 |
$ |
33.80 |
(1) |
$ |
28.83 |
$ |
37.40 |
(23) | |
Risk management gain |
4.27 |
4.89 |
(13) |
5.03 |
2.59 |
94 | |||||
Net sales price |
37.60 |
38.69 |
(3) |
33.86 |
39.99 |
(15) | |||||
Royalties |
(1.26) |
(4.39) |
(71) |
(1.08) |
(4.05) |
(73) | |||||
Operating expenses (4) |
(14.05) |
(17.43) |
(19) |
(13.18) |
(18.56) |
(29) | |||||
Transportation |
(1.62) |
(1.55) |
5 |
(1.72) |
(1.46) |
18 | |||||
Netback (1) |
$ |
20.67 |
$ |
15.32 |
35 |
$ |
17.88 |
$ |
15.92 |
12 |
(1) |
The terms "funds flow from operations" and their applicable per share amounts, and "netback" are non-GAAP measures. Please refer to the "Non-GAAP Measures" advisory section below for further details. |
(2) |
Capital expenditures include costs related to Property, Plant and Equipment. Includes the effect of capital carried from its partner under the Peace River Oil Partnership. |
(3) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(4) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $5 million or $1.30 per boe (2015 – $4 million or $0.47 per boe) for the three months ended and $15 million or $0.75 per boe (2015 – $13 million or $0.40 per boe) for the twelve months ended on a combined basis. |
(5) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
2016 Year-End Operational and Financial Highlights
Simplifying our Balance Sheet by Completing the Disposition Program
Improving Efficiencies with a Focused Portfolio
2016 Year-End Reserves Highlights
Foothold Reserve Bookings for Cardium Waterfloods
Asset Dispositions Accretive to Net Asset Value
Realigned Reserves in Peace River for Cold Flow Development
Recognizing the Efficiency Improvements and Potential in the Portfolio
Hitting the Ground Running in 2017
Operational Discussion
As a result of the asset dispositions and portfolio renovation over the past year, Penn West now holds a focused portfolio with industry leading positions in the Cardium, Peace River, and Alberta Viking areas.
The table below outlines select metrics in our key development areas for the three months ended December 31, 2016 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended December 31, 2016 | ||||
Production |
Liquids |
Operating |
Netback | ||
Cardium |
18,081 boe/d |
62% |
$14.79/boe |
$22.40/boe | |
Alberta Viking |
1,415 boe/d |
48% |
$19.59/boe |
$10.82/boe | |
Peace River(1) |
4,867 boe/d |
99% |
$1.00/boe |
$22.58/boe | |
Legacy Areas |
4,292 boe/d |
21% |
$26.54/boe |
($4.65)/boe | |
Key Development Areas |
28,655 boe/d |
61% |
$14.44/boe |
$17.81/boe |
(1) |
Net of carried operating costs |
In the fourth quarter of 2016, we completed our second half drilling program of 5 Cardium wells, 11 Alberta Viking wells, and 19 Peace River oil wells. The second half 2016 drilling program contributed over 3,000 boe per day of production on December 31, 2016.
The table below provides a summary of our operated activity during the fourth quarter:
Number of Wells | ||||||||
Drilled |
Completed |
On production | ||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||
Cardium |
6 |
6 |
5 |
5 |
2 |
2 | ||
Producer |
3 |
3 |
5 |
5 |
2 |
2 | ||
Injector |
3 |
3 |
0 |
0 |
0 |
0 | ||
Alberta Viking |
0 |
0 |
11 |
11 |
9 |
9 | ||
Peace River |
15 |
8.3 |
13 |
7.2 |
13 |
7.2 | ||
Total |
21 |
14.3 |
29 |
23.2 |
24 |
18.2 |
The table below outlines select reserve metrics in our key development areas, excluding assets sold or held for sale in 2017, for the year-ending December 31, 2016:
Area |
PDP |
1P |
2P | ||||
Volumes (MMBoe) |
Net Asset ($ million) |
Volumes (MMBoe) |
Net Asset ($ million) |
Volumes (MMBoe) |
Net Asset ($ million) | ||
Cardium |
56 |
$994 |
73 |
$1,070 |
102 |
$1,326 | |
Alberta Viking |
2 |
$35 |
3 |
$38 |
4 |
$51 | |
Peace River |
6 |
$121 |
8 |
$162 |
12 |
$216 | |
Legacy Areas |
7 |
$71 |
7 |
$73 |
10 |
$93 | |
Key Development Areas |
71 |
$1,221 |
91 |
$1,343 |
128 |
$1,686 |
Area |
2P Reserve Life |
Discounted Future |
Years of Development at | |||||
Cardium |
16.0 years |
$497 million |
5.1 years | |||||
Alberta Viking |
6.4 years |
$20 million |
1.5 years | |||||
Peace River |
6.1 years |
$19 million |
1.5 years |
Our 2017 total capital budget remains unchanged at $180 million from our previous announcement. Our capital program is focused on (i) Building a Cardium Waterflood Platform, (ii) Manufacturing Cold Flow in Peace River, (iii) Leveraging our Infrastructure Advantage in the Alberta Viking, and (iv) Pursuing New Ventures.
Details on expected capital spending allocation are as follows:
Capital Category |
Number of Wells |
Net Capital | ||
Cardium Waterflood Platform |
10 Producers, 45 Injectors |
$97 million | ||
Manufacture Cold Flow |
24 Producers |
$8 million | ||
Optimize Volumes with Viking |
11 Producers |
$15 million | ||
Pursue New Ventures |
7 Producers |
$15 million | ||
Total Development |
52 Producers, 45 Injectors |
$135 million | ||
Base Capital |
$25 million | |||
Total E&D Capital Expenditures |
$160 million | |||
Decommissioning Expenditures |
$20 million |
For more information on our 2017 capital program, please see our January 5, 2017 press release, http://pennwest.mediaroom.com/index.php?s=27585&item=135287.
Building a Cardium Waterflood Platform
Our strategy in the Cardium is based on integrated waterflood development in Pembina and Willesden Green, combining new horizontal producers with simultaneous vertical injection drilling to support reserve development and arrest base decline.
Our main focus in Pembina in 2017 will be in PCU#9, where we will drill three vertical injection wells to support an existing producing well in the first quarter. After breakup, we plan to drill an additional 3 horizontal wells plus 15 injection wells. We are also working with our partners in PCU#11 on preparing for our second half development program.
In 2016, in the J-Lease area of Pembina, we fracture-stimulated the two horizontal wells drilled in late September using a cemented liner system, and brought the wells on production in November. This year, we plan to focus on waterflood optimization opportunities in J-Lease, including converting several producing wells to injection. We are already seeing waterflood response in several areas based on earlier horizontal injector conversions.
In 2016, in the Crimson area of Willesden Green, we drilled the second and third horizontal wells of our three well development program in early October and completed all three wells in November. The wells were brought on production in early January and are performing in line with expectations. This year, we expect to drill 15 vertical injection wells prior to breakup and six injection wells in the second half of the year.
We are currently optimizing and upgrading some of our water injection infrastructure projects in preparation for our development program in the second half of the year.
Manufacturing Cold Flow in Peace River
This year, we will increase the development pace in the Peace River area with a 24 well program. We are currently carried on 90% of our capital and operating commitments through our joint venture partner, and we forecast the carry to finish by the end of 2017.
In 2016, in the Peace River area, we drilled and rig released the remaining 15 wells of our 19 well second half program in the fourth quarter. Through simultaneous drilling and facility build operations, we were able to reduce per well costs to $2.4 million, approximately 15% below budget.
In the first quarter 2017 we drilled 3 wells and brought on production 4 additional wells. We are currently running two rigs in the area and plan to bring on production an additional 8 wells during the third quarter.
Leveraging our Infrastructure Advantage in the Alberta Viking
In 2016, in the Alberta Viking, we brought 9 wells on production in the fourth quarter and 2 wells on production in the first quarter of 2017. These wells continue to perform ahead of expectations with average per well production rates, including oil rates, approximately 25% ahead of the average industry type curve in the play. We believe the success of these wells can be attributed to the novel approach, including energized fracs, we are taking with our completions in the area.
In the second half of the year, we have budgeted to drill 7 wells in the area. We are currently working on a small debottlenecking project in the area, which will allow us to expand the gas plant capacity at two of our gas plants.
Pursuing New Ventures
We have approximately 700 net sections of secondary rights in our portfolio. In the second half of the year, we have plans to expand our reach by testing the deeper hydrocarbon formations below our Cardium rights, primarily in the Mannville. We are encouraged by offsetting industry activity, showing the potential for high production rates and liquid yields in the 30-40 bbls/mmscf. We have budgeted to drill 3 Mannville wells, our first operated development into the multi-horizon potential across the Cardium area acreage, and are partnered on an additional 4 Mannville wells.
We are currently evaluating whether to reallocate some of the Mannville capital in the second half of the year elsewhere in the portfolio due to the recent fall in natural gas prices. We will continue to monitor our opportunities and commodity prices over spring breakup.
Hitting the Ground Running: Updated 2017 Guidance
Earlier this year, we re-evaluated a portion of our acreage in the outer Cardium and central Alberta that we originally planned to sell. These assets have meaningful deeper mineral rights in the Mannville that we intend to further evaluate in the near future. We decided to retain these assets and sell a portion of our freehold and gross overriding royalties for approximately equal proceeds. As a result, retained production in our key development areas in the fourth quarter of 2016 increased by approximately 3,500 boe per day to 28,655 boe per day.
We are increasing full year 2017 average production guidance to 30,500 – 31,500 boe per day, and remain confident in our ability to generate double-digit organic production growth from the fourth quarter of 2016 to the fourth quarter of 2017. We anticipate our 2017 capital program will be paid for fully with Funds Flow from Operations.
Updated Hedging Position
Our hedging program helps reduce the volatility of our Funds Flow from Operations, and thereby improves our ability to manage our ongoing capital programs. We target having hedges in place for approximately 25 percent to 50 percent of our crude oil exposure, net of royalties, and 20 percent to 50 percent of our gas exposure, net of royalties.
Our positions as of March 14, 2017 are as follows:
Q1 2017 |
Q2 2017 |
Q3 2017 |
Q4 2017 |
H1 2018 |
H2 2018 | ||
Oil Volume (bbl/d) |
8,600 |
7,800 |
7,400 |
7,900 |
1,000 |
1,000 | |
C$ WTI Price (C$/bbl) |
$67.67 |
$66.42 |
$66.42 |
$66.70 |
$71.00 |
$71.00 | |
US$ WTI Price (US$/bbl) (1) |
US$50.40 |
US$50.22 |
US$50.21 |
US$50.42 |
US$52.88 |
US$52.88 | |
Gas Volume (mcf/d) |
20,900 |
19,000 |
17,100 |
15,200 |
5,700 |
3,800 | |
AECO Price (C$/mcf) |
$3.04 |
$2.81 |
$2.83 |
$3.03 |
$2.87 |
$2.89 |
(1) |
US$ price implied using foreign exchange rates as at December 31, 2016 |
Senior Management Changes
We are pleased to announce that Mr. Andrew Sweerts, Penn West's Vice President of Business Development & Commercial, has assumed the position of Vice President of Production & Technical Services. Mr. Sweerts has 25 years of experience in leading asset & divestment and trading activities, directing projects and overseeing joint venture partnerships.
Replacing Mr. Sweerts as Vice President of Business Development and Commercial is Mr. Mark Hodgson. Mr. Hodgson brings over 16 years of experience in the industry most recently leading Bankers Petroleum Ltd. technical and commercial expansion efforts in Eastern Europe. Prior to New Ventures, Mr. Hodgson held positions managing service functions of Legal, Crude Marketing, Stakeholder Engagement, Supply Chain, Investor Relations, and Corporate Planning at various entities.
Conference Call Details
A conference call will be held to discuss the matters noted above at 6:30 am Mountain Time (8:30 am Eastern Time) on Wednesday, March 15, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1377599&s=1&k=4D74121AA7ACC2AF4E82852217FE413B
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 29, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 77593566, followed by the pound (#) key.
An updated corporate presentation, the year ended 2016 management's discussion and analysis and the audited consolidated financial statements are available on the Company's website at www.pennwest.com. Additionally, the year ended 2016 management's discussion and analysis and the audited consolidated financial statements will be posted on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Summary of Reserves
In 2016, we engaged Sproule Associates Limited ("Sproule"), an independent, qualified engineering firm, to evaluate one hundred percent of our proved and proved plus probable reserves. Sproule conducted an independent reserves evaluation of Penn West's reserves effective December 31, 2016. This evaluation was prepared in accordance with definitions, standards, and procedures set out in the Canadian Oil and Gas Evaluation Handbook ("COGEH") and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). The Sproule reserves evaluation was based on Sproule's December 31, 2016 product price forecast.
Under NI 51-101, proved reserves estimates are defined as having a high degree of certainty to be recoverable with a targeted 90 percent probability in aggregate that actual reserves recovered over time will equal or exceed proved reserve estimates. For proved plus probable reserves under NI 51-101, the targeted probability is an equal (50 percent) likelihood that the actual reserves to be recovered will be greater or less than the proved plus probable reserves estimate. The reserves estimates set forth below are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided herein.
The Summary of Reserves tables below are based on Sproule's evaluation at December 31, 2016 using Sproule's December 31, 2016 product price forecast. All reserve volumes are company gross unless otherwise noted.
Total Company Gross (WI) Reserves
As at December 31, 2016 |
||||||
Reserve |
Light & |
Heavy |
Natural |
Conventional |
Barrel of Oil | |
Estimates Category (1)(2) |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) | |
Proved |
||||||
Developed producing |
41 |
8 |
6 |
236 |
94 | |
Developed non-producing |
2 |
0 |
1 |
19 |
6 | |
Undeveloped |
10 |
2 |
1 |
23 |
17 | |
Total Proved |
54 |
10 |
7 |
278 |
117 | |
Probable |
21 |
5 |
3 |
97 |
44 | |
Total Proved plus Probable |
75 |
14 |
10 |
374 |
161 |
(1) |
Company gross (WI) reserves are before royalty burdens and exclude royalty interests. |
(2) |
Columns and rows may not add due to rounding. |
Total Company Net after Royalty Interest Reserves
As at December 31, 2016 |
||||||
Reserve |
Light & |
Heavy |
Natural |
Conventional |
Barrel of Oil | |
Estimates Category (1)(2) |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) | |
Proved |
||||||
Developed producing |
38 |
7 |
5 |
209 |
84 | |
Developed non-producing |
2 |
0 |
1 |
16 |
5 | |
Undeveloped |
9 |
2 |
1 |
21 |
15 | |
Total Proved |
49 |
9 |
6 |
246 |
105 | |
Probable |
19 |
4 |
2 |
87 |
39 | |
Total Proved plus Probable |
68 |
12 |
8 |
333 |
144 |
(1) |
Net after royalty reserves are working interest reserves including royalty interests and deducting royalty burdens. |
(2) |
Columns and rows may not add due to rounding. |
Additional reserve disclosures, as required under NI 51-101, will be contained in our Annual Information Form that will be filed on SEDAR at www.sedar.com.
Reconciliation of Company Gross (WI) Reserve
Light & |
Heavy |
Natural Gas |
Conventional |
Barrel of Oil | ||
Reconciliation Category (1) |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) | |
Total Proved |
||||||
December 31, 2015 |
104 |
33 |
12 |
353 |
208 | |
Extensions |
0 |
0 |
0 |
0 |
0 | |
Infill Drilling |
0 |
2 |
0 |
1 |
2 | |
Improved Recovery |
0 |
0 |
(0) |
(1) |
(0) | |
Technical Revisions |
1 |
1 |
0 |
34 |
7 | |
Acquisitions |
0 |
0 |
0 |
23 |
4 | |
Dispositions |
(42) |
(23) |
(3) |
(77) |
(81) | |
Economic Factors |
(2) |
(0) |
(0) |
(11) |
(5) | |
Production |
(8) |
(3) |
(1) |
(44) |
(20) | |
December 31, 2016 |
54 |
10 |
7 |
278 |
117 |
(1) |
Columns and rows may not add due to rounding. |
Light & |
Heavy |
Natural Gas |
Conventional |
Barrel of Oil | ||
Reconciliation Category (1) |
(mmbbl) |
(mmbbl) |
(mmbbl) |
(bcf) |
(mmboe) | |
Proved Plus Probable |
||||||
December 31, 2015 |
141 |
70 |
16 |
473 |
306 | |
Extensions |
0 |
1 |
0 |
0 |
1 | |
Infill Drilling |
0 |
3 |
0 |
1 |
3 | |
Improved Recovery |
2 |
0 |
0 |
1 |
2 | |
Technical Revisions |
(2) |
(28) |
0 |
29 |
(25) | |
Acquisitions |
0 |
0 |
0 |
31 |
5 | |
Dispositions |
(57) |
(28) |
(5) |
(103) |
(107) | |
Economic Factors |
(2) |
(0) |
(0) |
(14) |
(5) | |
Production |
(8) |
(3) |
(1) |
(44) |
(20) | |
December 31, 2016 |
75 |
14 |
10 |
374 |
161 |
(1) |
Columns and rows may not add due to rounding. |
Summary of Before Tax Net Present Values
As at December 31, 2016 |
|||||||
Net Present Value |
|||||||
$ millions (1) |
Undiscounted |
5% |
10% |
15% |
20% | ||
Proved |
|||||||
Developed producing |
$ |
2,629 |
1,811 |
1,396 |
1,148 |
983 | |
Developed non-producing |
105 |
82 |
67 |
55 |
47 | ||
Undeveloped |
410 |
181 |
74 |
18 |
(14) | ||
Total Proved |
3,143 |
2,075 |
1,537 |
1,221 |
1,015 | ||
Probable |
1,462 |
680 |
385 |
245 |
167 | ||
Total Proved plus Probable |
$ |
4,605 |
2,755 |
1,922 |
1,466 |
1,182 |
(1) |
Columns and rows may not add due to rounding. |
Net present values take into account wellbore abandonment and reclamation liabilities on reserve wells and are based on the price assumptions that are contained in the following table. It should not be assumed that the estimated future net revenues represent fair market value of the reserves. There is no assurance that the forecast price and cost assumptions will be attained and variances could be material.
Summary of Pricing and Inflation Rate Assumptions
Canadian |
|||||||||
WTI |
Light Sweet |
Natural Gas |
|||||||
Cushing, |
Crude |
AECO-C |
Exchange | ||||||
As at December 31 (1) |
Oklahoma |
40° API |
Spot |
Rate | |||||
Sproule Forecast |
($US/bbl) |
($Cdn/bbl) |
($Cdn/MMbtu) |
($US/$Cdn) | |||||
Year |
2016 |
2015 |
2016 |
2015 |
2016 |
2015 |
2016 |
2015 | |
Historical |
|||||||||
2012 |
94.19 |
94.19 |
86.57 |
86.57 |
2.43 |
2.43 |
1.00 |
1.00 | |
2013 |
97.98 |
97.98 |
93.27 |
93.27 |
3.13 |
3.13 |
0.97 |
0.97 | |
2014 |
93.00 |
93.00 |
93.99 |
93.99 |
4.50 |
4.50 |
0.91 |
0.91 | |
2015 |
48.80 |
48.80 |
57.45 |
57.45 |
2.70 |
2.70 |
0.78 |
0.78 | |
2016(2) |
43.32 |
45.00 |
52.80 |
55.20 |
2.18 |
2.25 |
0.76 |
0.75 | |
Forecast |
|||||||||
2017 |
55.00 |
60.00 |
65.58 |
69.00 |
3.44 |
2.95 |
0.78 |
0.80 | |
2018 |
65.00 |
70.00 |
74.51 |
78.43 |
3.27 |
3.42 |
0.82 |
0.83 | |
2019 |
70.00 |
80.00 |
78.24 |
89.41 |
3.22 |
3.91 |
0.85 |
0.85 | |
2020 |
71.40 |
81.20 |
80.64 |
91.71 |
3.91 |
4.20 |
0.85 |
0.85 | |
2021 |
72.83 |
82.42 |
82.25 |
93.08 |
4.00 |
4.28 |
0.85 |
0.85 | |
2022 |
74.28 |
83.65 |
83.90 |
94.48 |
4.10 |
4.35 |
0.85 |
0.85 | |
2023 |
75.77 |
84.91 |
85.58 |
95.90 |
4.19 |
4.43 |
0.85 |
0.85 | |
2024 |
77.29 |
86.18 |
87.29 |
97.34 |
4.29 |
4.51 |
0.85 |
0.85 | |
2025 |
78.83 |
87.48 |
89.03 |
98.80 |
4.40 |
4.59 |
0.85 |
0.85 | |
2026 |
80.41 |
88.79 |
90.81 |
100.28 |
4.50 |
4.67 |
0.85 |
0.85 | |
2027 |
82.02 |
n.a. |
92.63 |
n.a. |
4.61 |
n.a. |
0.85 |
n.a. |
(1) |
Costs & Prices escalated at 2.0% after 2027. |
(2) |
2016 Pricing was forecast at the time of the December 31, 2015 reserves report based on Sproule pricing. |
Future Development Capital
As at December 31, 2016 |
|||||
Future Development Capital |
|||||
$ millions (1) |
Total Proved |
Total Proved plus | |||
2017 |
$ |
43 |
86 | ||
2018 |
136 |
154 | |||
2019 |
113 |
160 | |||
2020 |
87 |
202 | |||
2021 |
32 |
79 | |||
2022 and subsequent |
5 |
7 | |||
Total, Undiscounted |
$ |
417 |
689 | ||
Total, Discounted @ 10% |
$ |
336 |
544 | ||
(1) Rows may not add due to rounding |
|||||
As at December 31, 2015 |
|||||
Future Development Capital |
|||||
$ millions (1) |
Total Proved |
Total Proved plus | |||
Total, Undiscounted |
$ |
692 |
1,528 | ||
Total, Discounted @ 10% |
$ |
526 |
1,099 |
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
Certain financial measures including Funds Flow from Operations, Funds Flow from Operations per share-basic, Funds Flow from Operations per share-diluted, netback, EBITDA and gross revenues included in this press release do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds Flow from Operations is cash flow from operating activities before changes in non-cash working capital, decommissioning expenditures and office lease settlements which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds Flow from Operations is used to assess the Company's ability to fund its planned capital programs. See "Calculation of Funds Flow from Operations" below for a reconciliation of Funds Flow from Operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Results of Operations – Netbacks" above for a calculation of the Company's netbacks. EBITDA is cash flow from operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. EBITDA as defined by Penn West's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Penn West's covenant calculations related to its syndicated bank facility and senior notes. Gross revenue is total revenues including realized risk management gains and losses on commodity contracts and is used to assess the cash realizations on commodity sales
Calculation of Funds Flow from Operations
Year ended December 31 | |||||||
(millions, except per share amounts) (1) |
2016 |
2015 | |||||
Cash flow from operating activities |
$ |
(137) |
$ |
175 | |||
Change in non-cash working capital |
97 |
(31) | |||||
Decommissioning expenditures |
11 |
36 | |||||
Office lease settlements |
4 |
- | |||||
Monetization of foreign exchange contracts |
(32) |
(95) | |||||
Settlements of normal course foreign exchange contracts |
(3) |
(40) | |||||
Monetization of transportation commitment |
(20) |
- | |||||
Realized foreign exchange loss – debt prepayments |
191 |
123 | |||||
Realized foreign exchange loss – debt maturities |
37 |
36 | |||||
Carried operating expenses (2) |
15 |
12 | |||||
Restructuring charges |
19 |
33 | |||||
Funds flow from operations |
$ |
182 |
$ |
249 | |||
Per share – funds flow from operations |
|||||||
Basic per share |
$ |
0.36 |
$ |
0.50 | |||
Diluted per share |
$ |
0.36 |
$ |
0.50 |
(1) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
(2) |
The effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our capital spending plans in 2017 and the associated funding of that spending, when we expect the carry from our joint venture partner in Peace River to expire, our updated expected full year production range, our expected production growth rate, our expected approach to development including the area-specific asset development plans described herein, the timing of development activities, the timing of pending and anticipated asset dispositions and the associated proceeds, our expectations for the ARO and the number of wellbores and associated environment liabilities going forward, our expectations for the LMR by the end of 2017, the changes expected in our reserves once certain things are recognized, that we are working on a project in the Alberta Viking to allow us to expand the gas plant capacity at our two gas plants, that we are evaluating whether or not to reallocate some of the capital spend based on continuing to monitor our opportunities and commodity prices over spring break-up, and our targeted hedging program.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: 2017 prices of US$54.07 per barrel of West Texas Intermediate light sweet oil and C$3.32 per mcf AECO gas, and a C$/US$ foreign exchange rate of $1.32; the terms and timing of asset sales to be completed; that we do not dispose of any material producing properties; our ability to execute our long-term plan as described herein and in our other disclosure documents and the impact that the successful execution of such plan will have on our Company and our shareholders; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully to current and new customers; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility and our ability to finance the repayment of our senior unsecured notes on maturity; and our ability to add production and reserves through our development and exploitation activities.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that we anticipate will accrue to our Company and our securityholders as a result of the successful execution of such plans do not materialize; the possibility that we are unable to execute some or all of our ongoing asset disposition program on favourable terms or at all; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, March 1, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is expected to release its year ended 2016 financial and operating results as well as its 2016 reserves results on Wednesday, March 15, 2017 before North American markets open. In addition, an updated corporate presentation, the year ended 2016 management's discussion and analysis and the audited consolidated financial statements will be available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
CONFERENCE CALL & WEBCAST DETAILS
A conference call will be held to discuss the matters noted above at 6:30 am Mountain Time (8:30 am Eastern Time) on Wednesday, March 15, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1377599&s=1&k=4D74121AA7ACC2AF4E82852217FE413B
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 29, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 77593566, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, Jan. 5, 2017 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce a 2017 total capital budget of $180 million. Our 2017 capital budget is expected to provide approximately 15% production growth in our key development areas from the fourth quarter of 2016 to the fourth quarter of 2017 and to provide ample flexibility to respond to commodity price as we utilize only 80% of available funds flow from operations.
"Our 2017 capital budget extends the work we completed in the second half of 2016 as we returned to drilling in our development areas," stated David French, President and Chief Executive Officer of Penn West. "In 2017, we will take a balanced and disciplined approach to our portfolio as we turn our objective to predictable growth. While living within our means, we will build on the basic platform of Penn West: industry leading Cardium waterflooding, cold flow heavy oil manufacturing in Peace River, and infrastructure advantaged Alberta Viking development. You will also see us step into testing new ventures as we explore commercialization of our material Mannville position. It will be an exciting year and sets us up nicely for enhanced growth through 2018 with the corporate engine of a repositioned balance sheet and industry leading base production declines."
Senior Management Changes
Penn West is announcing a leadership transition effective immediately. David Dyck, Chief Financial Officer ("CFO"), and Gregg Gegunde, Senior Vice President of Exploitation, Production and Delivery, will be departing the Company. Mr. Dyck has served in his current role for nearly three years, and Mr. Gegunde has served Penn West for over 18 years in a variety of leadership roles.
"These changes to Penn West's management reflect a natural evolution of the Company as we reposition as a smaller, highly focused growth company," commented Mr. French.
"David and Gregg have been key players of Penn West's leadership during a time of tremendous adversity. On behalf of the Board of Directors and Penn West's staff, I wish to offer my sincere thanks to them for their dedication and corporate stewardship which has enabled Penn West to chart a new beginning. We wish them the very best in their future endeavors."
We are pleased to announce that David Hendry, Penn West's Vice President of Finance for the last two years, will assume the position of CFO. Mr. Hendry is a Chartered Accountant, and brings over 25 years of finance experience, most recently as finance Vice President at Talisman Energy Inc. where he also served overseas for nine years in the Norway and U.K. North Sea offices. David started his career working nine years in public accounting, largely at PricewaterhouseCoopers. "I am very pleased that Dave is assuming the CFO mantle," said Mr. French. "Dave's commercial skills, leadership style, and facilitation of our banking relationships will help guide our turn to a growth agenda. His involvement in the Company's day-to-day financial affairs over the past two years means that his transition to CFO should be seamless."
2016 Fourth Quarter Operational Update
In the fourth quarter, we completed our second half drilling program of 5 Cardium wells, 11 Alberta Viking wells, and 19 Peace River oil wells. The second half 2016 drilling program contributed over 3,000 boe per day of production on December 31, 2016.
In the J-Lease area of Pembina, we successfully fracture-stimulated the 2 wells drilled in late September using a cemented liner system, and brought the wells on production November 9th. The wells encountered higher than expected pressure and have recently been optimized and are performing at 130 bbls of oil per day per well. In the Crimson area of Willesden Green, we drilled the second and third wells of our three well development program in early October and completed all three wells in November. Flowback results from the 3 wells averaged 1,100 bbls of oil per day per well. We expect to bring the three Crimson wells on full production later this month.
In the Peace River area, we drilled and rig released the remaining 17 wells of our 19 well second half program. Through simultaneous drilling and facility build operations, we were able to reduce per well costs to $2.4 million or approximately 15% below budget. The Peace River wells are averaging 300 bbls/d of oil in the first 30 days of production.
In the Alberta Viking, we brought 9 wells on production in the fourth quarter. These wells are performing significantly ahead of expectations with average to date per well production rates of 130 bbl per day of oil and 220 boe per day of total volumes. We expect to have the last 2 wells of the program on stream in early January. These well results provide confirmation of our target inventory and blend seamlessly into our existing processing capacity.
Fourth Quarter and Full Year Production
Fourth quarter volumes averaged approximately 38,500 boe per day, bringing our full year 2016 production to 55,000 boe per day. Full year 2016 Exploration and Development ("E&D") capital expenditures were approximately $80 million, plus $15 million for decommissioning expenditures.
Fourth quarter volumes in our key development areas averaged approximately 25,000 boe per day. These volumes now include additional royalty volume and minor non-core production throughout Alberta, and will form the basis of our 2017 growth projections.
Asset Disposition Program Finalization
In the fourth quarter, Penn West received an additional $20 million in proceeds, for a total of $95 million in proceeds in the second half of 2016. Penn West is in definitive agreement discussions to complete transactions for additional cash consideration of approximately $80 million. The Company anticipates receipt of the remaining cash proceeds early in the first quarter. These are subject to all necessary regulatory approvals and satisfaction of closing conditions customary in deals of this nature.
Senior Secured Debt
In the fourth quarter of 2016, Penn West reduced the capacity available under its revolving syndicated bank facility to $600 million from $1.2 billion. The reduced facility size is more appropriate for the Company after a meaningful debt reduction program throughout the year and a plan to fund future capital and other expenditures through funds flow from operations. This move is also expected to save the Company approximately $2.5 million annually in reduced standby fees. As at December 31, the Company had approximately $330 million drawn on its bank facility.
2017 Capital Budget Details
Build Cardium Waterflood Platform
Focus on integrated waterflood development in Pembina and Willesden Green, combining new horizontal producers with simultaneous injection drilling to support reserve development and arrest base decline. Plan contains a 55 well program, including 45 vertical injection wells to provide pressure support for 2015 & 2016 horizontal producers, and drill new horizontal producers in the second half of 2017.
Manufacture Cold Flow in Peace River
Increase the development pace in the Peace River area with a program of 24 producing wells. The Company is currently carried on 90% of our capital and operating commitments through our joint venture partner, and we forecast the carry to finish by the end of 2017. Attractive economics and de-risked acreage lead us to anticipate development in Peace River well beyond carry expiration.
Leverage Infrastructure Advantage with Viking Prospects
Optimize existing processing infrastructure and meaningful land base with an 11 well program, including 7 operated wells, in the Esther area. Our 2016 well results were best in class for the area and confirm our reservoir understanding and high-graded inventory and make full use of our local 15MMcfd gas processing capacity.
Pursue New Ventures
Extend our reach by drilling 3 Mannville wells in 2017, our first operated development into the multi-horizon potential across the Cardium area acreage, and partnered on an additional 4 Mannville wells. These wells have liquid yields in the 30-40 bbls/mmscf and deliver attractive economics competitive with the rest of our portfolio.
Overall, our $180MM total capital budget is expected to deliver full year 2017 production of 27,000 – 29,000 boe per day, approximately two-thirds of which will be liquids, with 2017 exit rates 15% over 2016 fourth quarter production volumes in our key development areas. Details on expected capital spending allocation are as follows:
Capital Category |
# of Wells |
Net Capital ($MM) |
Pembina Development |
6 Producers, 24 Vertical Injectors |
$33 |
Willesden Green Development |
4 Producers, 21 Vertical Injectors |
$34 |
Optimization |
$9 | |
Land & Seismic |
$6 | |
2018 Pre-Spend |
$10 | |
Other (incl. carry forward) |
$5 | |
Cardium Waterflood Platform |
10 Producers, 45 Vertical Injectors |
$97 |
Peace River Development |
24 Producers, 7 Stratigraphic |
$8 |
Manufacture Cold Flow |
24 Producers, 7 Stratigraphic |
$8 |
Alberta Viking Development |
7 Producers |
$13 |
Non-Operated Development |
4 Producers |
$1 |
Optimization |
$1 | |
Optimize Volumes with Viking |
11 Producers |
$15 |
Mannville Development |
3 Producers |
$9 |
Non-Operated Development |
4 Producers |
$6 |
Pursue New Ventures |
7 Producers |
$15 |
Total Development |
52 Producers, 45 Vertical Injectors |
$135 |
Base Capital |
$25 | |
Total E&D Capital Expenditures |
$160 | |
Decommissioning Expenditures |
$20 |
Updated Hedging Position
Penn West extended our hedge program to a six-quarter outlook and entered into additional hedges for 2017 and early 2018. We have now hedged approximately 50% of our forecasted net oil volumes and 30% of our forecasted net gas volumes for 2017.
Positions as of December 31, 2016 are as follows:
Q1 2017 |
Q2 2017 |
Q3 2017 |
Q4 2017 |
Q1 2018 |
Q2 2018 |
Q3 2018 |
Q4 2018 | |
Oil Volume (bbl/d) C$ WTI Price (C$/bbl) US$ WTI Price (US$/bbl) (1) |
8,600 $67.67 US$50.40 |
7,800 $67.42 US$50.22 |
7,400 $67.42 US$50.21 |
7,900 $67.70 US$50.42 |
1,000 $71.00 US$52.88 |
1,000 $71.00 US$52.88 |
- - - |
- - - |
Gas Volume (mmcf/d) |
21 |
19 |
17 |
15 |
4 |
4 |
4 |
4 |
(1) |
US$ price implied using foreign exchange rates as at December 31, 2016 |
Conference Call Details
A conference call will be held to discuss our 2017 capital budget at 6:30 a.m. Mountain Time (8:30 a.m. Eastern Time) on Thursday, January 5, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). A digital recording will be available for replay at 9:30 a.m. Mountain Time (11:30 a.m. Eastern Time), and will remain available until January 19, 2017, 9:59 p.m. Mountain Time (11:59 p.m. Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 44140662, followed by the pound (#) key.
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in Western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta. Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
This news release includes non-GAAP measures not defined under International Financial Reporting Standards ("IFRS") such as funds flow from operations. Such terms are explained under the heading "Non-GAAP Measures" in the most recently filed Management's Discussion and Analysis. Non-GAAP measures do not have any standardized meaning prescribed by GAAP and therefore may not be comparable to similar measures presented by other issuers.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our capital spending plans in 2017, our expected full year production, our expected production growth rate, our expected approach to development including the area-specific asset development plans described herein, the timing of development activities, the timing of pending and anticipated asset dispositions, and the anticipated reduction of standby fees associated with the capacity reduction under the revolving syndicated bank facility.
The forward-looking information is based on certain key expectations and assumptions made by Penn West, including expectations and assumptions concerning: prevailing and future commodity prices and currency exchange rates; applicable royalty rates and tax laws; interest rates; future well production rates and reserve volumes; operating costs; the timing of receipt of regulatory approvals; the performance of existing wells; the success obtained in drilling new wells; anticipated timing and results of capital expenditures; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the successful completion of acquisitions and dispositions; the availability and cost of labour and services; the state of the economy and the exploration and production business; the availability and cost of financing; and ability to market oil and natural gas successfully.
Although Penn West believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Penn West can give no assurances that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to: the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; interest rate fluctuations; marketing and transportation; loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; reliance on third parties; and changes in legislation, including but not limited to tax laws, royalties and environmental regulations. Readers are cautioned that the foregoing list of factors is not exhaustive.
Additional information on these and other factors that could affect Penn West, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein), Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Penn West's website.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, Dec. 30, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is expected to release its 2017 capital budget and corporate update on Thursday, January 5, 2017 before North American markets open.
CONFERENCE CALL DETAILS
A conference call will be held to discuss the matters noted above at 6:30 am Mountain Time (8:30 am Eastern Time) on Thursday, January 5, 2017.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). A digital recording will be available for replay at 9:30 am Mountain Time (11:30 am Eastern Time), and will remain available until January 19, 2017 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 44140662, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, Nov. 2, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the third quarter ended September 30, 2016. All figures are in Canadian dollars unless otherwise stated.
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
2016 |
2015 |
% change |
2016 |
2015 |
% change | ||||||
Financial (millions, except per share amounts) |
|||||||||||
Gross revenues (1,2) |
$ |
136 |
$ |
295 |
(54) |
$ |
576 |
$ |
995 |
(42) | |
Funds flow from operations (2) |
32 |
48 |
(33) |
134 |
210 |
(36) | |||||
Basic per share (2) |
0.06 |
0.10 |
(40) |
0.27 |
0.42 |
(36) | |||||
Diluted per share (2) |
0.06 |
0.10 |
(40) |
0.27 |
0.42 |
(36) | |||||
Net loss |
(232) |
(764) |
(70) |
(464) |
(1,040) |
(55) | |||||
Basic per share |
(0.46) |
(1.52) |
(70) |
(0.92) |
(2.07) |
(56) | |||||
Diluted per share |
(0.46) |
(1.52) |
(70) |
(0.92) |
(2.07) |
(56) | |||||
Capital expenditures (3) |
13 |
116 |
(89) |
32 |
371 |
(91) | |||||
Net Debt (4) |
$ |
484 |
$ |
2,414 |
(80) |
$ |
484 |
$ |
2,414 |
(80) | |
Operations |
|||||||||||
Daily production |
|||||||||||
Light oil and NGL (bbls/d) |
17,644 |
44,170 |
(60) |
29,502 |
49,267 |
(40) | |||||
Heavy oil (bbls/d) |
5,711 |
11,153 |
(49) |
9,844 |
11,992 |
(18) | |||||
Natural gas (mmcf/d) |
107 |
161 |
(34) |
127 |
169 |
(25) | |||||
Total production (boe/d) (5) |
41,233 |
82,198 |
(50) |
60,533 |
89,376 |
(32) | |||||
Average sales price |
|||||||||||
Light oil and NGL (per bbl) |
$ |
47.01 |
$ |
48.28 |
(3) |
$ |
42.20 |
$ |
50.91 |
(17) | |
Heavy oil (per bbl) |
21.67 |
31.20 |
(31) |
20.12 |
35.91 |
(44) | |||||
Natural gas (per mcf) |
$ |
2.46 |
$ |
2.99 |
(18) |
$ |
1.92 |
$ |
2.95 |
(35) | |
Netback per boe (5) |
|||||||||||
Sales price |
$ |
29.50 |
$ |
36.05 |
(18) |
$ |
27.86 |
$ |
38.45 |
(28) | |
Risk management gain |
5.58 |
2.83 |
97 |
5.19 |
1.91 |
>100 | |||||
Net sales price |
35.08 |
38.88 |
(10) |
33.05 |
40.36 |
(18) | |||||
Royalties |
(1.63) |
(2.72) |
(40) |
(1.04) |
(3.95) |
(74) | |||||
Operating expenses (6) |
(13.40) |
(20.45) |
(34) |
(12.99) |
(19.02) |
(32) | |||||
Transportation |
(1.71) |
(1.55) |
10 |
(1.74) |
(1.43) |
22 | |||||
Netback (2) |
$ |
18.34 |
$ |
14.16 |
30 |
$ |
17.28 |
$ |
15.96 |
8 |
(1) |
Includes realized gains and losses on commodity contracts and excludes gains and losses on foreign exchange hedges. |
(2) |
The terms "gross revenues", "funds flow from operations" and their applicable per share amounts, and "netback" are non-GAAP measures. Please refer to the "Calculation of Funds Flow from Operations" in the attached Management Discussion and Analysis and "Non-GAAP Measures" sections below. |
(3) |
Capital expenditures include costs related to Property, Plant and Equipment and Exploration and Evaluation. Includes the effect of capital carried by partners. |
(4) |
Net debt includes long-term debt and includes the effects of working capital and all cash held or cash offered for prepayment to lenders. |
(5) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(6) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $4 million or $1.04 per boe (2015 – $3 million or $0.44 per boe) for the three months ended and $11 million or $0.66 per boe (2015 – $9 million or $0.39 per boe) for the nine months ended on a combined basis. |
(7) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
President's Message
I am excited and humbled to be joining Penn West to lead the Company on the next stage of its journey. Through the hard work by my predecessor Dave Roberts and all of our employees, we were able to maneuver through a tremendously challenging time and come out the other side leaner, stronger, and much more competitive.
Over the coming months, we will reinforce the vision of Penn West as a premier oil producer. We have the discipline, drive, and ample financial flexibility to take the Company forward. The third quarter results mark an inflection point for Penn West. We delivered above expectations on volumes, continued our trend of cost management, restarted our development capital, and made steady progress on the final phases of getting the balance sheet right.
You will see us change the dialogue of the Company. With top tier assets in the Cardium, Viking, and Peace River, the Company will paint a picture and deliver on the promise of the core assets in the portfolio. These are extraordinary times. The best is yet to come.
Third Quarter Financial and Operational Highlights
Delivering on Expectations for Production and Costs
Back to Work in the Field
Further Steps in Strengthening the Balance Sheet
Select Metrics in Core Areas
The table below outlines select metrics in our core areas for the three and nine months ended September 30, 2016 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended September 30, 2016 | |||
Production |
Liquids Weighting |
Operating Cost |
Netback | |
Cardium |
16,168 boe/d |
63% |
$11.00/boe |
$23.00/boe |
Alberta Viking |
827 boe/d |
34% |
$14.00/boe |
$6.50/boe |
Peace River(1) |
4,916 boe/d |
98% |
$1.00/boe |
$18.50/boe |
Total Core |
21,911 boe/d |
70% |
$9.00/boe |
$21.00/boe |
Area |
Select Metrics – Nine Months Ended September 30, 2016 | |||
Production |
Liquids Weighting |
Operating Cost |
Netback | |
Cardium |
17,706 boe/d |
66% |
$9.50/boe |
$23.50/boe |
Alberta Viking |
1,004 boe/d |
38% |
$11.50/boe |
$5.50/boe |
Peace River(1) |
5,085 boe/d |
98% |
$1.00/boe |
$15.00/boe |
Total Core |
23,795 boe/d |
72% |
$8.00/boe |
$21.00/boe |
(1) Net of carried operating costs |
Operated Development Activity
Our renewed financial flexibility allowed us to restart drilling and completions operations in the third quarter. The Company increased its capital budget by approximately $40 million in the second half to accelerate development in the Cardium and Alberta Viking. The Company initiated a four rig drilling program: one rig in the Alberta Viking, one rig in the Cardium, and two rigs previously planned in the Peace River area.
The table below provides a summary of our operated activity during the third quarter:
Number of Wells | ||||||
Drilled |
Completed |
On production | ||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |
Cardium |
2.0 |
2.0 |
0.0 |
0.0 |
0.0 |
0.0 |
Alberta Viking |
11.0 |
11.0 |
0.0 |
0.0 |
0.0 |
0.0 |
Peace River |
2.0 |
1.1 |
2.0 |
1.1 |
2.0 |
1.1 |
Total Core |
15.0 |
14.1 |
2.0 |
1.1 |
2.0 |
1.1 |
Cardium
In the J-Lease area of Pembina, we successfully drilled our two well program in late September. Both wells have now been fracture stimulated using a cemented liner system and will be brought on production shortly. We also focused on waterflood optimization and reservoir surveillance to optimize injection targets in key Cardium areas. We converted one horizontal production well to a water injection well during the quarter to provide pressure support to the surrounding area.
In the Crimson area of Willesden Green, we drilled the first of our three well development program in early October. We expect to finish drilling and complete the wells in late November. During the quarter, we initiated work on upgrading some waterflood infrastructure in the area to provide support to the existing horizontal producers.
Alberta Viking
In the third quarter, the Company engaged a drilling rig on an 11 well development program in the Alberta Viking in Esther. Drilling was finished ahead of schedule and per well drilling costs are trending approximately $50 thousand below budget. The wells were all drilled with one mile laterals and will be completed with a cemented liner system and an average of 36 stages per well. Completions will commence in early November and we expect to have the wells on production in early December.
Peace River
During the third quarter, we initiated a two rig development program in Peace River. We drilled and brought on production two wells (1.1 net) of our 19 well second half development program. Both wells are currently producing above type curve. Despite initial wet weather delays in restarting drilling, we remain on track to complete the program by the end of the year. We continue to have approximately 90 percent of our working interest expenditures paid by our joint venture partner.
We previously announced a multi-year gas supply agreement in support of a proposed power plant in the Peace River area. The power plant project is proceeding forward with the design of pipeline and facilities for all four major project areas which will utilize the power plant, with construction of the Harmon Valley South gathering system commencing the first week of November. Start up and commissioning of the power plant is expected in December of 2017, at which time our agreement will allow us to meet associated gas conservation targets and significantly reduce our environmental impact in this area.
Senior Secured Debt
In the third quarter, we closed dispositions for total proceeds of approximately $75 million. Year-to-date we have generated approximately $1.4 billion in asset disposition proceeds. As a result, our third quarter net debt was approximately $484 million, down from $2.1 billion at year-end 2015; which is outlined as follows:
(millions) |
As at September 30, 2016 |
As at December 31, 2015 |
Syndicated bank facility and senior notes |
$912 |
$1,940 |
Cash |
($448) |
($2) |
Working capital deficiency (1) |
$20 |
$182 |
Net debt |
$484 |
$2,120 |
(1) Includes Accounts receivable, Other current assets, Accounts payable and accrued liabilities and excludes cash offered for prepayment. |
During the quarter, we offered $448 million of cash on hand from asset dispositions to our senior noteholders to prepay amounts owing to them at par and on a pro rata basis. Subsequent to the quarter, our noteholders agreed to accept $437 million of the prepayment offer with the remainder of the cash applied to our bank debt. This prepayment lowered the outstanding principal on our senior notes to approximately $139 million, lowered the effective interest rate on our debt, and reduced the number of noteholders from 36 down to two.
On September 30, our Senior Debt to EBITDA was 1.95 times relative to a 4.5 times covenant threshold, which marks a meaningful step down in leverage. Going forward, we expect to remain in full compliance with all of our financial covenants.
The table below outlines the calculation of our Senior Debt to EBITDA covenant as at the end of the third quarter:
(millions, except ratios) |
Trailing Twelve months ended September 30, 2016 |
Cash flow from operating activities |
$(66) |
Change in non-cash working capital |
$72 |
Decommissioning expenditures |
$16 |
Financing |
$145 |
Realized gain on foreign exchange hedges on prepayments |
$(18) |
Realized foreign exchange loss on debt prepayments |
$177 |
Restructuring expenses – cash portion |
$20 |
EBITDA |
$346 |
EBITDA contribution from assets sold (1) |
$(105) |
EBITDA as defined by debt covenants |
$241 |
Total senior notes |
$576 |
Syndicated bank facility advances |
$336 |
Total long-term debt |
$912 |
Repayment from disposition proceeds (2) |
$(448) |
Letters of credit – financial (3) |
$5 |
Total senior debt |
$469 |
Senior Debt to EBITDA |
1.95x |
(1) |
Consists of EBITDA contributions from assets that have been disposed in the prior 12 months. |
(2) |
Was offered to noteholders prior to September 30, 2016 and repaid in October 2016. |
(3) |
Letters of credit that are classified as financial are included in the Senior Debt calculation per the debt agreements. |
Updated Hedging Position
Our hedging program helps reduce the volatility of our funds flow from operations, and thereby improves our ability to align capital programs going forward. We target having hedges in place for approximately 25 percent to 40 percent of our crude oil exposure, net of royalties, and 40 percent to 50 percent of our gas exposure, net of royalties.
Our positions as of November 2, 2016 are as follows:
Q4 2016 |
Q1 2017 |
Q2 2017 |
Q3 2017 |
Q4 2017 |
2018 | |
Oil Volume (bbl/d) |
8,000 |
6,800 |
3,800 |
3,800 |
3,800 |
- |
C$ WTI Price (C$/bbl) |
$69.27 |
$67.65 |
$66.30 |
$66.30 |
$66.30 |
- |
US$ WTI Price (US$/bbl) (1) |
US$51.88 |
US$50.51 |
US$49.54 |
US$49.58 |
US$49.72 |
- |
Gas Volume (mmcf/d) |
19 |
17 |
15 |
13 |
11 |
4 |
AECO Price (C$/mcf) |
$2.96 |
$3.02 |
$2.73 |
$2.74 |
$2.99 |
$2.89 |
(1) US$ price implied foreign exchange rates as at October 31, 2016 |
Updated 2016 Guidance
As a result of the asset dispositions closed in the third quarter, with associated production of approximately 6,000 boe per day, and additional dispositions anticipated in the fourth quarter, we are adjusting our full year 2016 production guidance to 52,000 – 55,000 boe per day from 55,000 – 57,000 boe per day. In our Core Areas, full year 2016 production guidance is unchanged at 22,000 – 24,000 boe per day.
Our full year 2016 capital budget remains unchanged at $90 million, plus $15 million allocated for decommissioning expenditures.
Full year corporate operating costs and G&A cost guidance is unchanged at $13.50 – $14.50 per boe and $2.50 – $2.90 per boe, respectively.
Our guidance for full year 2016 is as follows:
Metric |
Guidance Range | |
Average Corporate Production |
boe/d |
52,000 – 55,000 |
Average Core Area Production |
boe/d |
22,000 – 24,000 |
E&D Capital Expenditures |
$ millions |
$90 |
Decommissioning Expenditures |
$ millions |
$15 |
Corporate Operating Costs (1) |
$/boe |
$13.50 – $14.50 |
G&A Costs |
$/boe |
$2.50 – $2.90 |
(1) Net of carried expenses in Peace River |
We are in the process of finalizing our 2017 budget. We still anticipate spending up to $150 million in total capital, including decommissioning expenditures, next year. The Cardium will remain the foundation of our development program supported by incremental growth in the Alberta Viking and meaningful cash generation at Peace River. We expect next year's program will deliver core production growth of at least 10% from the end of 2016 to the end of 2017 and will be fully paid for by funds flow from operations. We expect to formalize these plans and update the market in the coming months.
Conference Call Details
A conference call will be held to discuss the matters noted above at 9:00 am Mountain Time (11:00 am Eastern Time) on Wednesday, November 2, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1281273&s=1&k=28EA646FAFFFE0BE427BB3122083F436
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
This news release includes non-GAAP measures not defined under International Financial Reporting Standards ("IFRS") including funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues. Such terms are explained under the heading "Non-GAAP Measures" in the attached Management's Discussion and Analysis. Non-GAAP measures do not have any standardized meaning prescribed by GAAP and therefore may not be comparable to similar measures presented by other issuers.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that over the coming months we will reinforce the vision of Penn West as a premier oil producer, that we have the discipline, drive, and ample financial flexibility to take the Company forward, that the dialogue of the Company will change and that the Company will paint a picture and deliver on the promise of the core assets in the portfolio, that some discretionary expenses, including turnarounds and workovers, will be completed in the four quarter, that our second half development plan remains on time and on budget and is expected to increase our exit volumes by approximately 3,000 boe per day, that the Company remains on track to generate total disposition proceeds in the second half of the year between $100 million and $200 million, inclusive of the sales closed in the last quarter, that we will require less office space in the future as we have limited the same and scope of our operations this year, that as a result of dispositions and more anticipated in the fourth quarter, adjustments to the full year 2016 production guidance but maintaining annual production in the core areas, 2016 capital budget and full year guidance for both operating costs and G&A costs, that both wells in the J-Lease area of Pembina will be brought on production shortly, that in the Crimson area of Willesden Green we expect to finish drilling and complete the wells in late November, that in the Alberta Viking the per well drilling costs are trending approximately $50 thousand below budget and will be completed with a cemented liner system and an average of 36 stages per well, with completions in the area commencing in early November and we expect to have the wells on production in early December, in the Peace River area that we remain on track to complete the program by the end of the year and continue to have approximately 90 percent of our working interest expenditures paid by our joint venture partner, that the construction of the Harmon Valley South gathering system will commence the first week of November, that the startup and commissioning of the power plant is expected in December of 2017, at which time our agreement will allow us to meet associated gas conservation targets and significantly reduce our environmental impact in this area, that going forward we expect to remain in full compliance with all of our financial covenants, that we target having hedges in place for approximately 25 percent to 40 percent of our crude oil exposure, net of royalties, and 40 percent to 50 percent of our gas exposure, net of royalties, that we expect to spend approximately $150 million of total capital, including decommissioning expenditures in 2017, that the Cardium will remain the foundation of our development program supported by incremental growth in the Alberta Viking and meaningful cash generation at Peace River, that next year's capital program will deliver core production growth of at least 10% from the end of 2016 to the end of 2017 and will be fully paid by our funds flow from operations, and that we will formalize these plans and update the market in the coming months.
The forward-looking information is based on certain key expectations and assumptions made by Penn West, including expectations and assumptions concerning: prevailing and future commodity prices and currency exchange rates; applicable royalty rates and tax laws; interest rates; future well production rates and reserve volumes; operating costs; the timing of receipt of regulatory approvals; the performance of existing wells; the success obtained in drilling new wells; anticipated timing and results of capital expenditures; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the successful completion of acquisitions and dispositions; the availability and cost of labour and services; the state of the economy and the exploration and production business; the availability and cost of financing; and ability to market oil and natural gas successfully.
Although Penn West believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Penn West can give no assurances that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to: the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; interest rate fluctuations; marketing and transportation; loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; reliance on third parties; and changes in legislation, including but not limited to tax laws, royalties and environmental regulations. Readers are cautioned that the foregoing list of factors is not exhaustive.
Additional information on these and other factors that could affect Penn West, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein), Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Penn West's website.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
See also "Forward-Looking Statements" in the attached Management's Discussion and Analysis.
MANAGEMENT'S DISCUSSION AND ANALYSIS
For the three and nine months ended September 30, 2016
This management's discussion and analysis of financial condition and results of operations ("MD&A") of Penn West Petroleum Ltd. ("Penn West", the "Company", "we", "us", "our") should be read in conjunction with the Company's unaudited interim condensed consolidated financial statements for the three and nine months ended September 30, 2016 and the Company's audited consolidated financial statements and MD&A for the year ended December 31, 2015. The date of this MD&A is November 1, 2016. All dollar amounts contained in this MD&A are expressed in millions of Canadian dollars unless noted otherwise.
Certain financial measures such as funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues included in this MD&A do not have a standardized meaning prescribed by International Financial Reporting Standards ("IFRS") and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. This MD&A also contains oil and gas information and forward-looking statements. Please see the Company's disclosure under the headings "Non-GAAP Measures", "Oil and Gas Information", and "Forward-Looking Statements" included at the end of this MD&A.
Quarterly Financial Summary
(millions, except per share and production amounts)(unaudited)
Three months ended (1) |
Sep. 30 2016 |
June 30 2016 |
Mar. 31 2016 |
Dec. 31 2015 |
Sep. 30 2015 |
June 30 2015 |
Mar. 31 2015 |
Dec. 31 2014 | |||||||||
Gross revenues (2) |
$ |
136 |
$ 209 |
$ |
231 |
$ |
273 |
$ |
295 |
$ |
360 |
$ |
340 |
$ |
473 | ||
Funds flow from operations |
32 |
55 |
47 |
39 |
48 |
85 |
77 |
146 | |||||||||
Basic per share |
0.06 |
0.11 |
0.09 |
0.08 |
0.10 |
0.17 |
0.15 |
0.29 | |||||||||
Diluted per share |
0.06 |
0.11 |
0.09 |
0.08 |
0.10 |
0.17 |
0.15 |
0.29 | |||||||||
Net loss |
(232) |
(132) |
(100) |
(1,606) |
(764) |
(28) |
(248) |
(1,772) | |||||||||
Basic per share |
(0.46) |
(0.26) |
(0.20) |
(3.20) |
(1.52) |
(0.06) |
(0.49) |
(3.57) | |||||||||
Diluted per share |
(0.46) |
(0.26) |
(0.20) |
(3.20) |
(1.52) |
(0.06) |
(0.49) |
(3.57) | |||||||||
Dividends declared |
- |
- |
- |
- |
5 |
5 |
5 |
70 | |||||||||
Per share |
$ |
- |
$ - |
$ |
- |
$ |
- |
$ |
0.01 |
$ |
0.01 |
$ |
0.01 |
$ |
0.14 | ||
Production |
|||||||||||||||||
Liquids (bbls/d) (3) |
23,355 |
41,848 |
53,012 |
53,339 |
55,323 |
63,222 |
65,343 |
64,124 | |||||||||
Natural gas (mmcf/d) |
107 |
130 |
144 |
144 |
161 |
168 |
177 |
198 | |||||||||
Total (boe/d) |
41,233 |
63,568 |
77,010 |
77,398 |
82,198 |
91,164 |
94,905 |
97,143 |
(1) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
(2) |
Includes realized gains and losses on commodity contracts and excludes gains and losses on foreign exchange hedges. |
(3) |
Includes crude oil and natural gas liquids. |
Calculation of Funds Flow from Operations
(millions, except per share amounts) |
Three months ended September 30 |
Nine months ended September 30 | |||||||
2016 |
2015 |
2016 |
2015 | ||||||
Cash flow from operating activities |
$ |
(98) |
$ |
59 |
$ |
(93) |
$ |
148 | |
Change in non-cash working capital |
16 |
(54) |
103 |
- | |||||
Decommissioning expenditures |
1 |
9 |
5 |
25 | |||||
Monetization of foreign exchange contracts |
- |
- |
(32) |
(63) | |||||
Settlements of normal course foreign exchange contracts |
(9) |
(6) |
(3) |
(31) | |||||
Monetization of transportation commitment |
- |
- |
(20) |
- | |||||
Realized foreign exchange loss – debt prepayments |
113 |
15 |
113 |
59 | |||||
Realized foreign exchange loss – debt maturities |
- |
- |
36 |
36 | |||||
Carried operating expenses (1) |
4 |
3 |
11 |
9 | |||||
Restructuring charges – cash portion |
5 |
22 |
14 |
27 | |||||
Funds flow from operations (2) |
$ |
32 |
$ |
48 |
$ |
134 |
$ |
210 | |
Per share – funds flow from operations |
|||||||||
Basic per share |
$ |
0.06 |
$ |
0.10 |
$ |
0.27 |
$ |
0.42 | |
Diluted per share |
$ |
0.06 |
$ |
0.10 |
$ |
0.27 |
$ |
0.42 |
(1) |
The effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
(2) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
The decline in funds flow from operations from 2015 was mainly due to lower production volumes as the Company successfully closed several asset dispositions in 2015 and 2016 as it focused on strengthening its balance sheet. Additionally, declines in the commodity price environment, specifically on heavy oil and natural gas, contributed to the decrease.
During the third quarter of 2016, the Company recorded a realized foreign exchange loss as it used the disposition proceeds from the Saskatchewan Viking disposition to prepay senior notes of US$416 million, CAD$38 million, £25 million and €3 million (2015 - US$56 million, CAD$6 million, £2 million and €1 million).
In the first half of 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes and permanently disposed of a pipeline commitment and received $20 million of proceeds from the sale.
Business Strategy
In 2016, the Company successfully closed several asset dispositions for total proceeds of $1.4 billion. The proceeds from these asset sales were applied against long-term debt and significantly improved the Company's financial position which resulted in compliance with all senior debt financial covenants at September 30, 2016. The Company expects to remain in compliance with all of its financial covenants for the foreseeable future.
During the third quarter of 2016, Penn West progressed on its disposition strategy and closed a number of transactions for total proceeds of approximately $75 million and associated average production of approximatively 6,000 boe per day. The Company will continue to streamline its asset portfolio and focus its operations within the Cardium, Viking and Peace River areas in Alberta. By disposing of properties outside of its core areas, the Company anticipates a lower cost structure in both unit operating costs and abandonment liabilities.
During the third quarter of 2016, the Company restarted development activities within its core areas. Within its core areas, the Company believes its asset base will grow reserves, increase organic production, and increase funds flow from operations under the current commodity price environment.
Business Environment
The following table outlines quarterly averages for benchmark prices and Penn West realized prices for the last five quarters.
Q3 2016 |
Q2 2016 |
Q1 2016 |
Q4 2015 |
Q3 2015 | |||||||
Benchmark prices |
|||||||||||
WTI crude oil ($US/bbl) |
$ |
44.95 |
$ |
45.59 |
$ |
33.45 |
$ |
42.18 |
$ |
46.43 | |
Edm mixed sweet par price (CAD$/bbl) |
54.68 |
54.70 |
40.67 |
52.85 |
56.17 | ||||||
NYMEX Henry Hub ($US/mcf) |
2.81 |
1.95 |
2.09 |
2.27 |
2.77 | ||||||
AECO Index (CAD$/mcf) |
2.26 |
1.32 |
1.97 |
2.56 |
2.85 | ||||||
Penn West average sales price (1) |
|||||||||||
Light oil (CAD$/bbl) |
53.97 |
53.48 |
37.44 |
50.20 |
52.60 | ||||||
Heavy oil (CAD$/bbl) |
21.67 |
25.18 |
14.76 |
25.40 |
31.20 | ||||||
NGL (CAD$/bbl) |
17.91 |
18.05 |
12.75 |
19.53 |
15.24 | ||||||
Total liquids (CAD$/bbl) |
40.81 |
42.98 |
29.86 |
42.16 |
44.83 | ||||||
Natural gas (CAD$/mcf) |
2.46 |
1.42 |
1.96 |
2.54 |
2.99 | ||||||
Benchmark differentials |
|||||||||||
WTI - Edm Light Sweet ($US/bbl) |
(2.96) |
(3.07) |
(3.69) |
(2.46) |
(3.42) | ||||||
WTI - WCS Heavy ($US/bbl) |
$ |
(13.50) |
$ |
(13.30) |
$ |
(14.24) |
$ |
(14.49) |
$ |
(13.27) |
(1) Excludes the impact of realized hedging gains or losses. |
Crude Oil
During the third quarter of 2016, crude oil prices fluctuated between $US40 and $US50 per barrel as concerns regarding high inventory levels and ongoing speculation of an OPEC agreement to limit production resulted in range bound volatility. WTI averaged $US44.95 per barrel for the quarter.
Canadian light oil differentials strengthened in the third quarter to $US2.96 per barrel below WTI, while heavy oil differentials weakened to $US13.50 per barrel less than WTI as production re-started at oil sands operations in Northern Alberta after the Fort McMurray wildfires.
As at September 30, 2016, the Company had the following crude oil hedging positions in place:
Reference Price |
Term |
Price ($/Barrel) |
Volume (Barrels/day) |
WTI |
Oct 2016 – Dec 2016 |
CAD $69.27 |
8,000 |
WTI |
Jan 2017 – Mar 2017 |
CAD $69.37 |
3,000 |
WTI |
Jan 2017 – Dec 2017 |
CAD $66.07 |
3,500 |
Natural Gas
NYMEX Henry Hub natural gas prices remained strong throughout the quarter averaging $US2.81 per mcf because of warm weather in North America and reduced production growth from the United States.
AECO prices increased during the third quarter of 2016 as intra-Alberta demand returned to normal levels with oil sands projects in Fort McMurray returning to production following the wildfires. Ongoing short term restrictions on the TransCanada pipeline system continued to affect supply and led to volatility in the AECO spot prices.
Penn West had the following natural gas hedging positions in place as at September 30, 2016.
Reference Price |
Term |
Price ($/mcf) |
Volume (mcf/day) |
AECO |
Oct 2016 – Dec 2016 |
CAD $2.96 |
18,700 |
AECO |
Jan 2017 – Mar 2017 |
CAD $3.03 |
15,000 |
AECO |
Apr 2017 – Jun 2017 |
CAD $2.70 |
13,200 |
AECO |
Jul 2017 – Sep 2017 |
CAD $2.71 |
11,300 |
AECO |
Oct 2017 – Dec 2017 |
CAD $3.00 |
9,400 |
AECO |
Jan 2017 – Dec 2017 |
CAD $2.92 |
1,900 |
AECO |
Jan 2018 – Dec 2018 |
CAD $2.89 |
3,800 |
Average Sales Prices
Three months ended |
Nine months ended | |||||||||
2016 |
2015 |
% change |
2016 |
2015 |
% change | |||||
Light oil (per bbl) |
$ |
53.97 |
$ |
52.60 |
3 |
$ |
46.16 |
$ |
55.72 |
(17) |
Commodity gain (loss) (per bbl) (1) |
15.14 |
5.82 |
>100 |
11.11 |
2.09 |
>100 | ||||
Light oil net (per bbl) |
69.11 |
58.42 |
18 |
57.27 |
57.81 |
(1) | ||||
Heavy oil (per bbl) |
21.67 |
31.20 |
(31) |
20.12 |
35.91 |
(44) | ||||
NGL (per bbl) |
17.91 |
15.24 |
18 |
15.79 |
17.81 |
(11) | ||||
Natural gas (per mcf) |
2.46 |
2.99 |
(18) |
1.92 |
2.95 |
(35) | ||||
Commodity gain (per mcf) (1) |
0.13 |
0.03 |
>100 |
0.23 |
0.48 |
(52) | ||||
Natural gas net (per mcf) |
2.59 |
3.02 |
(14) |
2.15 |
3.43 |
(37) | ||||
Weighted average (per boe) |
29.50 |
36.05 |
(18) |
27.86 |
38.45 |
(28) | ||||
Commodity gain (loss) (per boe) (1) |
5.58 |
2.83 |
97 |
5.19 |
1.91 |
>100 | ||||
Weighted average net (per boe) |
$ |
35.08 |
$ |
38.88 |
(10) |
$ |
33.05 |
$ |
40.36 |
(18) |
(1) Realized risk management gains and losses on commodity contracts are included in gross revenues. |
RESULTS OF OPERATIONS
Production
Three months ended September 30 |
Nine months ended September 30 | |||||
Daily production |
2016 |
2015 |
% change |
2016 |
2015 |
% change |
Light oil (bbls/d) |
14,236 |
39,052 |
(64) |
25,658 |
43,009 |
(40) |
Heavy oil (bbls/d) |
5,711 |
11,153 |
(49) |
9,844 |
11,992 |
(18) |
NGL (bbls/d) |
3,408 |
5,118 |
(33) |
3,844 |
6,258 |
(39) |
Natural gas (mmcf/d) |
107 |
161 |
(34) |
127 |
169 |
(25) |
Total production (boe/d) |
41,233 |
82,198 |
(50) |
60,533 |
89,376 |
(32) |
The Company closed several asset dispositions in 2016 with associated average production of approximately 30,000 boe per day as it focused on reducing its debt levels. This led to a decline in production from the comparative periods. Significant dispositions in 2016 include:
In 2016, the Company experienced strong production results due to well performance coming in ahead of expectations and improvements in its base production reliability. During the third quarter of 2016, average production within the Company's core plays totalled 21,911 boe per day and was as follows:
During the third quarter of 2016, Penn West restarted capital activity and drilled two wells in the Cardium, one well in Peace River and 11 wells within the Alberta Viking. All wells are planned to be completed in the fourth quarter of 2016.
Netbacks
Three months ended September 30 | |||||||||
2016 |
2015 | ||||||||
Liquids (bbl) |
Natural Gas (mcf) |
Combined (boe) |
Combined | ||||||
Operating netback: |
|||||||||
Sales price (1) |
$ |
40.81 |
$ |
2.46 |
$ |
29.50 |
$ |
36.05 | |
Commodity gain (2) |
9.23 |
0.13 |
5.58 |
2.83 | |||||
Royalties |
(4.45) |
0.34 |
(1.63) |
(2.72) | |||||
Transportation |
(1.37) |
(0.36) |
(1.71) |
(1.55) | |||||
Operating costs |
(16.40) |
(1.58) |
(13.40) |
(20.45) | |||||
Netback |
$ |
27.82 |
$ |
0.99 |
$ |
18.34 |
$ |
14.16 | |
(bbls/d) |
(mmcf/d) |
(boe/d) |
(boe/d) | ||||||
Production |
23,355 |
107 |
41,233 |
82,198 |
(1) |
Excluded from the netback calculation during the third quarter was $3 million of other income (2015 - $nil) including sulphur sales. |
(2) |
Realized risk management gains and losses on commodity contracts. |
(3) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
Overall, netbacks have increased from 2015 due to lower operating costs due to successful cost reduction activities, increased commodity gains due to the Company's active hedging program and a reduction in royalties due to the lower commodity price environment. The weak commodity price environment partially offset this, specifically related to heavy oil and natural gas prices. Operating Costs includes the effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership of $4 million or $1.04 per boe on a combined basis (2015 - $3 million or $0.44 per boe).
Nine months ended September 30 | |||||||||
2016 |
2015 | ||||||||
Liquids (bbl) |
Natural Gas (mcf) |
Combined (boe) |
Combined | ||||||
Operating netback: |
|||||||||
Sales price (1) |
$ |
36.68 |
$ |
1.92 |
$ |
27.86 |
$ |
38.45 | |
Commodity gain (2) |
7.25 |
0.23 |
5.19 |
1.91 | |||||
Royalties |
(3.02) |
0.44 |
(1.04) |
(3.95) | |||||
Transportation |
(1.56) |
(0.35) |
(1.74) |
(1.43) | |||||
Operating costs |
(14.89) |
(1.58) |
(12.99) |
(19.02) | |||||
Netback |
$ |
24.46 |
$ |
0.66 |
$ |
17.28 |
$ |
15.96 | |
(bbls/d) |
(mmcf/d) |
(boe/d) |
(boe/d) | ||||||
Production |
39,346 |
127 |
60,533 |
89,376 |
(1) |
Excluded from the netback calculation in 2016 was $28 million of other income (2015 - $10 million), mainly related to the proceeds received by the Company from permanently disposing of a pipeline commitment during the first quarter. |
(2) |
Realized risk management gains and losses on commodity contracts. |
(3) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
For the first nine months of 2016, operating costs includes the effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership of $11 million or $0.66 per boe on a combined basis (2015 - $9 million or $0.39 per boe).
Production Revenues
Revenues from the sale of liquids and natural gas consisted of the following:
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Liquids |
$ |
110 |
$ |
250 |
(56) |
$ |
501 |
$ |
837 |
(40) |
Natural gas |
26 |
45 |
(42) |
75 |
158 |
(53) | ||||
Gross revenues (1) |
$ |
136 |
$ |
295 |
(54) |
$ |
576 |
$ |
995 |
(42) |
(1) |
Includes realized risk management gains on commodity contracts which totaled $21 million for the three months ended September 30, 2016 (2015 - $22 million) and $86 million for the nine months ended September 30, 2016 (2015 - $47 million). |
Gross revenues are lower than the comparative periods due to a significant decrease in production volumes as the Company successfully closed several asset dispositions. The decline in the commodity price environment also contributed to the decrease which was partially offset by the weakening of the Canadian dollar compared to the US dollar from the prior year.
Reconciliation of Change in Production Revenues
(millions) |
||
Gross revenues – January 1 – September 30, 2015 |
$ |
995 |
Decrease in liquids production |
(308) | |
Decrease in liquids prices (1) |
(46) | |
Decrease in natural gas production |
(39) | |
Decrease in natural gas prices (1) |
(44) | |
Increase in other income (2) |
18 | |
Gross revenues – January 1 – September 30, 2016 |
$ |
576 |
(1) |
Includes realized risk management gains and losses on commodity contracts. |
(2) |
Other income of $28 million (2015 - $10 million) for the nine months ended September 30, 2016 relates mainly to proceeds received by the Company from permanently disposing of a pipeline commitment during the first quarter. |
Royalties
Three months ended September 30 |
Nine months ended September 30 | |||||||||
2016 |
2015 |
% change |
2016 |
2015 |
% change | |||||
Royalties (millions) |
$ |
6 |
$ |
20 |
(70) |
$ |
17 |
$ |
96 |
(82) |
Average royalty rate (1) |
5% |
7% |
(29) |
4% |
10% |
(70) | ||||
$/boe |
$ |
1.63 |
$ |
2.72 |
(40) |
$ |
1.04 |
$ |
3.95 |
(74) |
(1) Excludes effects of risk management activities. |
Royalties have decreased from the comparative periods mainly due to the impact of asset disposition activity completed in 2015 and 2016 and decreases in the commodity price environment. In the second quarter of 2016, the Company received its annual gas cost allowance invoice which resulted in the release of an $8 million provision related to the asset disposition activity completed in 2015.
Expenses
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | ||||
Operating |
$ |
55 |
$ |
159 |
(65) |
$ |
227 |
$ |
474 |
(52) |
Transportation |
7 |
12 |
(42) |
29 |
35 |
(17) | ||||
Financing |
22 |
40 |
(45) |
103 |
120 |
(14) | ||||
Share-based compensation |
$ |
4 |
$ |
(4) |
>100 |
$ |
11 |
$ |
3 |
>100 |
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(per boe) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | ||||
Operating (1) |
$ |
13.40 |
$ |
20.45 |
(34) |
$ |
12.99 |
$ |
19.02 |
(32) |
Transportation |
1.71 |
1.55 |
10 |
1.74 |
1.43 |
22 | ||||
Financing |
5.70 |
5.26 |
8 |
6.20 |
4.91 |
26 | ||||
Share-based compensation |
$ |
1.23 |
$ |
(0.51) |
>100 |
$ |
0.70 |
$ |
0.11 |
>100 |
(1) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $4 million or $1.04 per boe (2015 - $3 million or $0.44 per boe) for the three months ended September 30, 2016 and $11 million or $0.66 per boe (2015 - $9 million or $0.39 per boe) for the nine months ended September 30, 2016. |
Operating
The Company significantly improved its cost structure from 2015 as it progressed on several cost saving initiatives focused on repair & maintenance and workover categories. Additionally, in 2015 and 2016, Penn West closed several asset dispositions and high-graded its portfolio by disposing of non-core, high operating cost properties. In 2016, the Company benefited from the continued weak commodity price environment which resulted in cost savings across the industry.
The Company deferred a number of discretionary expenses, primarily turnarounds and workover activities, to later in the year. As a result, the Company is maintaining its annual operating cost per boe target for 2016 of $13.50 - $14.50 per boe.
Operating costs for the third quarter of 2016 included a realized loss of $1 million (2015 – $6 million) and for the nine months ended September 30, 2016 included a realized loss of $5 million (2015 – $10 million) on electricity contracts.
Financing
At September 30, 2016, the Company had a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion and an extendible five-year term (May 6, 2019 maturity date). The syndicated bank facility contains provisions for stamping fees on bankers' acceptances and LIBOR loans and standby fees on unutilized credit lines that vary depending on certain financial ratios. At September 30, 2016, the Company had $848 million of unused credit capacity available.
At September 30, 2016, the value of the Company's senior notes was $576 million (December 31, 2015 – $1.5 billion).
In the first nine months of 2016, the Company prepaid senior notes in aggregate of $627 million (2015 - $358 million) and a total of $340 million (2015 – $56 million) of indebtedness was repaid under the Company's syndicated bank facility.
In September 2016, the Company offered an additional $448 million of net proceeds received from dispositions during the year for prepayment of outstanding senior notes. The offer to holders of the Company's senior notes was substantially accepted and $437 million was subsequently prepaid in October 2016. The remaining $11 million was used to repay indebtedness on the Company's syndicated bank facility.
Including the payments in October, in 2016 the Company has completed prepayments to its lenders totalling $1,415 million (2015 - $414 million) which includes prepayments of senior notes of $1,064 million (2015 - $358 million) and repayments of indebtedness under the Company's syndicated bank facility of $351 million (2015 – $56 million).
There were no senior note issuances in either 2016 or 2015.
Summary information on our senior notes outstanding as at September 30, 2016 is as follows:
Issue date |
Amount (millions) |
Term |
Average |
Weighted average remaining | |
2007 Notes |
May 31, 2007 |
US$92 |
8 – 15 years |
6.86% |
1.8 |
2008 Notes |
May 29, 2008 |
US$103, CAD$14 |
8 – 12 years |
7.30% |
2.0 |
UK Notes |
July 31, 2008 |
£16 |
10 years |
6.95% (2) |
1.8 |
2009 Notes |
May 5, 2009 |
US$20 (3), £7, €3 |
5 – 10 years |
9.83% (4) |
2.3 |
2010 Q1 Notes |
March 16, 2010 |
US$71 |
5 – 15 years |
6.68% |
2.9 |
2010 Q4 Notes |
December 2, 2010, |
US$58, CAD$13 |
5 – 15 years |
5.94% |
4.9 |
2011 Notes |
November 30, 2011 |
US$36, CAD$8 |
5 – 10 years |
5.49% |
3.5 |
(1) |
Average interest rate can fluctuate based on debt to EBITDA ratio which expires on March 30, 2017, the date the covenant relief period ends with the bank syndicate and noteholders. |
(2) |
These notes currently bear interest at 7.95 percent in Pounds Sterling, however, contracts were entered to fix the interest rate at 6.95 percent in Canadian dollars and to fix the exchange rate on the repayment. |
(3) |
A portion of the 2009 Notes have equal repayments, which began in 2013 with a repayment of US$5 million, and extend over the remaining years. |
(4) |
The Company entered contracts to fix the interest rate on the Pounds Sterling and Euro tranches, at 10.15 percent and 10.22 percent, to 9.15 percent and 9.22 percent, respectively, and to fix the exchange rate on repayment. |
Penn West's debt structure includes short-term financings under its syndicated bank facility and long-term financing through its senior notes. Financing charges in 2016 decreased compared to 2015 as the Company reduced debt levels as it applied disposition proceeds to re-pay indebtedness on the Company's syndicated bank facility and pre-paid outstanding senior notes, which resulted in lower interest charges.
In May 2015, the Company finalized amended agreements with the lenders under its syndicated bank facility and with the holders of its senior notes which resulted in amended financial covenants and led to increases in the fee structure. The fee structure on the Company's senior notes will change during the amendment period (up until March 30, 2017) as follows:
Senior debt to EBITDA ratio |
Basis points per | |
Less than or equal to 3:1 |
50 | |
Greater than 3:1 and less than or equal to 4:1 |
100 | |
Greater than 4:1 and less than or equal to 4.5:1 |
150 | |
Greater than 4.5:1 |
200 |
See "Liquidity and Capital Resources – Liquidity" for further details on the amendments.
The interest rates on any non-hedged portion of the Company's syndicated bank facility are subject to fluctuations in short-term money market rates as advances on the syndicated bank facility are generally made under short-term instruments. As at September 30, 2016, 37 percent (December 31, 2015 – 24 percent) of Penn West's long-term debt instruments was exposed to changes in short-term interest rates.
Share-Based Compensation
Share-based compensation expense relates to the Company's Stock Option Plan (the "Option Plan"), Restricted Share Unit Plan ("RSU"), Deferred Share Unit Plan ("DSU") and Performance Share Unit Plan ("PSU").
Share-based compensation consisted of the following:
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | ||||
Options |
$ |
1 |
$ |
1 |
- |
$ |
2 |
$ |
3 |
(33) |
RSU – liability method |
1 |
(4) |
>100 |
3 |
- |
100 | ||||
RSU – equity method |
1 |
- |
100 |
4 |
- |
100 | ||||
PSU |
1 |
(1) |
>100 |
2 |
- |
100 | ||||
Share-based compensation |
$ |
4 |
$ |
(4) |
>100 |
$ |
11 |
$ |
3 |
>100 |
The share price used in the fair value calculation of the RSU plan (liability method), PSU and DSU obligations at September 30, 2016 was $2.35 (September 30, 2015 – $0.60). Share-based compensation related to the DSU was insignificant in both periods.
General and Administrative Expenses
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
(millions, except per boe amounts) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | |||||
Gross |
$ |
22 |
$ |
36 |
(39) |
$ |
65 |
$ |
113 |
(42) | |
Per boe |
5.82 |
4.74 |
23 |
3.91 |
4.61 |
(15) | |||||
Net |
14 |
23 |
(39) |
43 |
68 |
(37) | |||||
Per boe |
$ |
3.74 |
$ |
3.02 |
24 |
$ |
2.59 |
$ |
2.79 |
(7) |
In 2015 and 2016, the Company has significantly decreased its workforce due to asset disposition activity which led to reductions in the absolute expense. On a per boe basis, the lower production volumes from asset disposition activity contributed to the increase on a quarterly basis. For 2016, the Company is continuing to forecast G&A per boe at $2.50 - $2.90.
Restructuring Expense
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
(millions, except per boe amounts) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | |||||
Restructuring |
$ |
111 |
$ |
22 |
>100 |
$ |
122 |
$ |
27 |
>100 | |
Per boe |
$ |
29.25 |
$ |
2.90 |
>100 |
$ |
7.34 |
$ |
1.12 |
>100 |
In 2016, the Company recorded a charge totaling $108 million (2015 – nil) on certain office lease commitments as they were classified as onerous contracts. This charge was the result of completing several asset dispositions in 2016 and the associated reductions in staff, consequently the Company requires less office space in the future.
During the first nine months of 2016, the Company reduced its headcount in response to reduced activity levels and the low commodity price environment. As the Company continues to progress through its disposition strategy, further headcount reductions will occur resulting in additional restructuring expenses.
Depletion, Depreciation, Impairment and Accretion
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions, except per boe amounts) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Depletion and depreciation ("D&D") |
$ |
62 |
$ |
155 |
(60) |
$ |
295 |
$ |
510 |
(42) |
D&D expense per boe |
16.57 |
20.38 |
(19) |
17.87 |
20.88 |
(14) | ||||
PP&E impairment |
18 |
834 |
(98) |
223 |
834 |
(73) | ||||
PP&E impairment per boe |
4.75 |
110.29 |
(96) |
13.45 |
34.18 |
(61) | ||||
E&E impairment |
51 |
- |
100 |
89 |
- |
100 | ||||
E&E impairment per boe |
13.44 |
- |
100 |
5.37 |
- |
100 | ||||
Accretion of decommissioning provision |
4 |
9 |
(56) |
18 |
28 |
(36) | ||||
Accretion expense per boe |
$ |
1.19 |
$ |
1.23 |
(3) |
$ |
1.09 |
$ |
1.15 |
(5) |
The Company's D&D expense has decreased from the comparative periods mainly due to asset dispositions that closed in 2015 and 2016 and impairment charges recorded in 2015.
During the third quarter of 2016, the Company recorded $13 million of PP&E impairment ($18 million before-tax) as certain natural gas properties located within British Columbia were recorded at the lesser of fair value less costs to sell and their carrying amount. Also during the third quarter of 2016, the Company impaired certain E&E properties located within British Columbia as it no longer has future plans for development in this area. The E&E impairment recorded totaled $37 million ($51 million before-tax). The Company plans to focus capital activities within its core areas in the Cardium, Viking and Peace River all within Alberta
During the first half of 2016, the Company entered agreements to dispose of properties as it progressed on its disposition strategy and increase its financial flexibility. As the book value of these assets exceeded the fair value received, non-cash impairment charges of $150 million ($205 million before-tax) related to PP&E and $27 million ($38 million before-tax) related to E&E were recorded.
Taxes
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Deferred tax recovery |
$ |
(83) |
$ |
(258) |
(68) |
$ |
(186) |
$ |
(252) |
(26) |
During the third quarter of 2016, the deferred tax recovery was related to the restructuring charge on office lease contracts and the impairment of the deferred funding asset held under the Cordova Joint Venture and associated E&E impairment. On a year-to-date basis, the deferred tax recovery also includes non-cash impairment charges recorded on dispositions during the first half of the year.
Foreign Exchange
Penn West records unrealized foreign exchange gains or losses to translate the US., UK and Euro denominated senior notes and the related accrued interest to Canadian dollars using the exchange rates in effect on the balance sheet date. Realized foreign exchange gains or losses are recorded upon repayment of the senior notes.
The split between realized and unrealized foreign exchange losses is as follows:
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Realized foreign exchange loss on maturities |
$ |
- |
$ |
- |
- |
$ |
(36) |
$ |
(36) |
- |
Realized foreign exchange loss on pre-payments |
(113) |
(15) |
>100 |
(113) |
(59) |
92 | ||||
Unrealized foreign exchange gain (loss) |
94 |
(89) |
>100 |
235 |
(162) |
>100 | ||||
Foreign exchange gain (loss) |
$ |
(19) |
$ |
(104) |
(82) |
$ |
86 |
$ |
(257) |
>100 |
During 2016, Penn West repaid senior notes in an aggregate amount of US$141 million (2015 - US$193 million and CAD$50 million) as part of normal course maturities. Additional amounts of US$416 million, CAD$38 million, £25 million and €3 million (2015 - US$258 million, CAD$24 million, £10 million and €2 million) of senior notes were prepaid as a result of the offers made at par to its noteholders using asset disposition proceeds during the year.
The unrealized gain in 2016 is due to the strengthening of the Canadian dollar relative to the US dollar.
Net loss
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
(millions, except per share amounts) |
2016 |
2015 |
% |
2016 |
2015 |
% | |||||
Net loss |
$ |
(232) |
$ |
(764) |
(70) |
$ |
(464) |
$ |
(1,040) |
(55) | |
Basic per share |
(0.46) |
(1.52) |
(70) |
(0.92) |
(2.07) |
(56) | |||||
Diluted per share |
$ |
(0.46) |
$ |
(1.52) |
(70) |
$ |
(0.92) |
$ |
(2.07) |
(56) |
The net loss in the third quarter of 2016 was mainly attributed to a realized foreign exchange loss on debt prepayments, a restructuring charge on office lease contracts, the impairment of the deferred funding asset held under the Cordova Joint Venture and associated E&E impairment.
The net loss in the first nine months of 2016 also included non-cash impairment charges as a result of asset disposition activity during the first half of the year. This was partially offset by unrealized foreign exchange gains due to the strengthening of the Canadian dollar compared to the US dollar.
Capital Expenditures
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Land acquisition and retention |
$ |
1 |
$ |
- |
100 |
$ |
2 |
$ |
1 |
100 |
Drilling and completions |
13 |
93 |
(86) |
31 |
256 |
(88) | ||||
Facilities and well equipping |
4 |
31 |
(87) |
20 |
122 |
(84) | ||||
Geological and geophysical |
- |
- |
- |
2 |
2 |
- | ||||
Corporate |
- |
1 |
(100) |
- |
5 |
(100) | ||||
Capital carried by partners |
(5) |
(9) |
(44) |
(23) |
(15) |
53 | ||||
Exploration and development capital expenditures (1) |
13 |
116 |
(89) |
32 |
371 |
(91) | ||||
SR&ED tax credits |
- |
- |
- |
(3) |
- |
(100) | ||||
Property dispositions, net |
(76) |
1 |
>(100) |
(1,401) |
(411) |
>100 | ||||
Total capital expenditures |
$ |
(63) |
$ |
117 |
>(100) |
$ |
(1,372) |
$ |
(40) |
>100 |
(1) Capital expenditures include costs related to Property, Plant and Equipment and Exploration and Evaluation activities. |
During the third quarter of 2016, the Company advanced on its second half 2016 capital program which resulted in two wells drilled in the Cardium, one well in Peace River and 11 wells in the Alberta Viking. Capital activities in the fourth quarter of 2016 will be focused on completion and tie-in of these wells in addition to further drilling within the Cardium and Peace River.
In 2016, the Company reduced its capital program in comparison to 2015 as a result of the low commodity price environment as it targets its annual expenditures to be within funds flow from operations.
The Company made significant progress on its asset disposition initiatives in 2016 as it closed its Saskatchewan Viking disposition in June 2016 for total proceeds of approximately $975 million, subject to closing adjustments, and closed its Slave Point disposition located in Northern Alberta in April 2016 for total proceeds of approximately $148 million, subject to closing adjustments. During the third quarter of 2016, the Company progressed further on its disposition strategy and closed several, non-core property dispositions. The Company will continue to advance on its disposition initiatives in the fourth quarter of 2016.
Exploration and evaluation ("E&E") capital expenditures
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
E&E capital expenditures |
$ |
- |
$ |
3 |
(100) |
$ |
- |
$ |
10 |
(100) |
In 2016, E&E expenditures were minimal as the Company focused activities on development within its core plays.
Loss (gain) on asset dispositions
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Loss (gain) on asset dispositions |
$ |
2 |
$ |
1 |
100 |
$ |
(30) |
$ |
(94) |
(68) |
During the first nine months of 2016, Penn West closed several asset dispositions, including the Saskatchewan Viking disposition as it continued to reduce debt and focus its asset portfolio. For the first nine months of 2016, $9 million of transaction costs were incurred (2015 - $3 million).
Environmental and Climate Change
The oil and gas industry has a number of environmental risks and hazards and is subject to regulation by all levels of government. Environmental legislation includes, but is not limited to, operational controls, site restoration requirements and restrictions on emissions of various substances produced in association with oil and natural gas operations. Compliance with such legislation could require additional expenditures and a failure to comply may result in fines and penalties which could, in the aggregate and under certain assumptions, become material.
Penn West is dedicated to reducing the environmental impact from its operations through its environmental programs which include resource conservation, water management and site abandonment/reclamation/remediation. Operations are continuously monitored to minimize environmental impact and allocate sufficient capital to reclamation and other activities to mitigate the impact on the areas in which the Company operates.
Liquidity and Capital Resources
Capitalization
September 30, 2016 |
December 31, 2015 |
% change | |
Common shares issued, at market (1) |
1,181 |
588 |
>100 |
Bank loans and long-term notes |
912 |
1,940 |
(53) |
Cash |
(447) |
(2) |
>100 |
Total enterprise value (2) |
1,646 |
2,526 |
(35) |
(1) The share price at September 30, 2016 was $2.35 (December 31, 2015 - $1.17). |
(2) Certain comparative figures have been reclassified to correspond with current period presentation. |
The Company's working capital deficiency at September 30, 2016 was $20 million (December 31, 2015 – $182 million) which excludes the current portion of deferred funding asset, risk management, long-term debt, provisions and $448 million of cash that was offered as a pre-payment to its lenders.
Dividends
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(millions, except per share amounts) |
2016 |
2015 |
% |
2016 |
2015 |
% | ||||
Dividends declared |
$ |
- |
$ |
5 |
(100) |
$ |
- |
$ |
15 |
(100) |
Per share |
- |
0.01 |
(100) |
- |
0.03 |
(100) | ||||
Dividends paid (1) |
$ |
- |
$ |
5 |
(100) |
$ |
- |
$ |
80 |
(100) |
(1) The Company previously had a dividend reinvestment plan, includes amounts funded through that plan. |
On September 1, 2015, Penn West announced that its Board of Directors approved the suspension of the dividend until further notice, following the October 15, 2015 payment.
Liquidity
The Company has a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion and an extendible five-year term (May 6, 2019 maturity date). For further details on the Company's debt instruments, please refer to the "Financing" section of this MD&A.
The Company actively manages its debt portfolio and considers opportunities to reduce or diversify its debt capital structure. Management contemplates both operating and financial risks and takes action as appropriate to limit the Company's exposure to certain risks. Management maintains close relationships with the Company's lenders and agents to monitor credit market developments. These actions and plans aim to increase the likelihood of maintaining the Company's financial flexibility and capital program, supporting the Company's ability to capture opportunities in the market and execute longer-term business strategies.
The Company has a number of covenants related to its syndicated bank facility and senior notes. On September 30, 2016, the Company was in compliance with all of these financial covenants which consisted of the following:
Limit |
September 30, 2016 | |
Senior debt to EBITDA (1) |
Less than 4.5:1 |
1.95 |
Total debt to EBITDA (1) |
Less than 4.5:1 |
1.95 |
Senior debt to capitalization |
Less than 50% |
16% |
Total debt to capitalization |
Less than 55% |
16% |
(1) |
EBITDA is calculated in accordance with Penn West's lending agreements wherein unrealized risk management gains and losses and impairment provisions are excluded. |
The table below outlines the Company's senior debt to EBITDA calculation as at September 30, 2016:
Three months ended |
Trailing | |||||||||
(millions, except ratios) |
Sep. 30 2016 |
June 30 2016 |
Mar. 31 2016 |
Dec. 31 2015 |
Sep. 30 2016 | |||||
Cash flow from operating activities |
$ |
(98) |
$ |
(56) |
$ |
61 |
$ |
27 |
$ |
(66) |
Change in non-cash working capital |
16 |
61 |
26 |
(31) |
72 | |||||
Decommissioning expenditures |
1 |
2 |
2 |
11 |
16 | |||||
Financing |
22 |
41 |
40 |
42 |
145 | |||||
Realized gain on foreign exchange hedges on prepayments |
(9) |
- |
- |
(9) |
(18) | |||||
Realized foreign exchange loss – debt prepayments |
113 |
- |
- |
64 |
177 | |||||
Restructuring expenses – cash portion |
5 |
3 |
6 |
6 |
20 | |||||
EBITDA |
$ |
50 |
$ |
51 |
$ |
135 |
$ |
110 |
$ |
346 |
EBITDA contribution from assets sold (1) |
(105) | |||||||||
EBITDA as defined by debt agreements |
$ |
241 | ||||||||
Long-term debt |
$ |
912 | ||||||||
Repayment from disposition proceeds (2) |
(448) | |||||||||
Letters of credit – financial (3) |
5 | |||||||||
Total senior debt |
$ |
469 | ||||||||
Senior debt to EBITDA |
1.95 |
(1) Consists of EBITDA contributions from assets that have been disposed in the prior 12 months. |
(2) Was offered to noteholders prior to September 30, 2016 and repaid in October 2016. |
(3) Letters of credit that are classified as financial are included in the senior debt calculation per the debt agreements. |
(4) Certain comparative figures have been reclassified to correspond with current period presentation. |
In September 2016, the Company offered $448 million of net proceeds received from dispositions during the year for prepayment of outstanding senior notes. The offer to holders of the Company's senior notes was substantially accepted and $437 million was subsequently pre-paid in October 2016. The remaining $11 million was used to repay indebtedness on the Company's syndicated bank facility. As the offer was made prior to September 30, 2016, the $448 million was excluded from long-term debt in the debt to EBITDA calculation, consistent with the Company's credit agreements.
On September 30, 2016, including the benefit of the $448 million offered to the Company's lenders, pro forma long-term debt was $464 million.
In May 2015, the Company finalized amending agreements with the lenders under its syndicated bank facility and with the holders of its senior notes to, among other things, amend its financial covenants as follows:
The Company also agreed to the following:
Financial Instruments
The Company had the following financial instruments outstanding as at September 30, 2016. Fair values are determined using external counterparty information, which is compared to observable market data. Penn West limits its credit risk by executing counterparty risk procedures which include transacting only with institutions within its syndicated bank facility or with high credit ratings and by obtaining financial security in certain circumstances.
Notional |
Remaining Term |
Pricing |
Fair value | |||
Natural gas |
||||||
AECO Swaps |
14,000 mcf/d |
Oct/16 – Dec/16 |
$3.05/mcf |
$ |
1 | |
AECO Swaps |
4,700 mcf/d |
Oct/16 – Dec/16 |
$2.69/mcf |
- | ||
AECO Swaps |
15,000 mcf/d |
Jan/17 – Mar/17 |
$3.03/mcf |
- | ||
AECO Swaps |
13,200 mcf/d |
Apr/17 – Jun/17 |
$2.70/mcf |
- | ||
AECO Swaps |
11,300 mcf/d |
Jul/17 – Sep/17 |
$2.71/mcf |
- | ||
AECO Swaps |
9,400 mcf/d |
Oct/17 – Dec/17 |
$3.00/mcf |
- | ||
AECO Swaps |
1,900 mcf/d |
Jan/17 – Dec/17 |
$2.92/mcf |
- | ||
AECO Swaps |
3,800 mcf/d |
Jan/18 – Dec/18 |
$2.89/mcf |
- | ||
Crude Oil |
||||||
WTI Swaps |
3,000 bbl/d |
Oct/16 – Dec/16 |
$64.58/bbl |
- | ||
WTI Swaps |
5,000 bbl/d |
Oct/16 – Dec/16 |
$72.08/bbl |
5 | ||
WTI Swaps |
3,000 bbl/d |
Jan/17 – Mar/17 |
$69.37/bbl |
1 | ||
WTI Swaps |
3,500 bbl/d |
Jan/17 – Dec/17 |
$66.07/bbl |
(1) | ||
Electricity swaps |
||||||
Alberta Power Pool |
25 MW |
Oct/16 – Dec/16 |
$49.90/MWh |
(2) | ||
Foreign exchange forwards on senior notes |
||||||
3 to 15-year initial term |
US$25 |
2017 |
1.000 CAD/USD |
8 | ||
Cross currency swaps |
||||||
10-year initial term |
£57 |
2018 |
2.0075 CAD/GBP, 6.95% |
(17) | ||
10-year initial term |
£20 |
2019 |
1.8051 CAD/GBP, 9.15% |
(1) | ||
10-year initial term |
€10 |
2019 |
1.5870 CAD/EUR, 9.22% |
(1) | ||
Total |
$ |
(7) |
The components of risk management gain are as follows:
Three months ended September 30 |
Nine months ended September 30 | ||||||||||
(millions) |
2016 |
2015 |
% change |
2016 |
2015 |
% change | |||||
Realized |
|||||||||||
Settlement of commodity contracts |
|||||||||||
and assignment |
$ |
21 |
$ |
22 |
(5) |
$ |
84 |
$ |
29 |
>100 | |
Monetization of commodity contracts |
- |
- |
- |
2 |
18 |
(89) | |||||
Settlement of foreign exchange contracts |
9 |
6 |
50 |
3 |
31 |
(90) | |||||
Monetization of foreign exchange contracts |
- |
- |
- |
32 |
63 |
(49) | |||||
Total realized risk management gain |
30 |
28 |
7 |
121 |
141 |
(14) | |||||
Unrealized |
|||||||||||
Commodity contracts |
(5) |
48 |
>(100) |
(41) |
6 |
>(100) | |||||
Electricity swaps |
- |
(3) |
>(100) |
2 |
4 |
(50) | |||||
Crude oil assignment |
- |
4 |
(100) |
- |
(3) |
(100) | |||||
Foreign exchange contracts |
4 |
20 |
(80) |
(43) |
(23) |
87 | |||||
Cross-currency swaps |
(1) |
7 |
>(100) |
(29) |
17 |
>(100) | |||||
Total unrealized risk management gain (loss) |
(2) |
76 |
>(100) |
(111) |
1 |
>(100) | |||||
Risk management gain |
$ |
28 |
$ |
104 |
(73) |
$ |
10 |
$ |
142 |
(93) |
In the first nine months of 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes and unwound AECO swap contracts totalling 14,100 mcf per day.
Outlook
As a result of the asset dispositions closed in the third quarter of 2016 with associated average production of approximately 6,000 boe per day, combined with additional dispositions anticipated in the fourth quarter, the Company is updating its full year 2016 production guidance to 52,000 – 55,000 boe per day from 55,000 – 57,000 boe per day. Guidance for average core area production, exploration and development ("E&D") capital expenditures, decommissioning expenditures and operating costs per boe all remain unchanged as previously disclosed in the Company's August 4, 2016 press release. G&A per boe also remains unchanged, as previously disclosed in the Company's January 28, 2016 press release.
Metric |
2016 Guidance Range | |
Average Corporate Production |
boe per day |
52,000 – 55,000 |
Average Core Area Production |
boe per day |
22,000 – 24,000 |
E&D Capital Expenditures |
$ millions |
$90 |
Decommissioning Expenditures |
$ millions |
$15 |
Operating Costs (1) |
$/boe |
$13.50 – $14.50 |
G&A Costs |
$/boe |
$2.50 – $2.90 |
(1) Net of carried operating expenses under the Peace River Oil Partnership. |
This outlook section is included to provide shareholders with information about Penn West's expectations as at November 1, 2016 for production, exploration and development capital expenditures, operating costs per boe and G&A per boe for 2016 and readers are cautioned that the information may not be appropriate for any other purpose. This information constitutes forward-looking information. Readers should note the assumptions, risks and discussion under "Forward-Looking Statements" and are cautioned that numerous factors could potentially impact Penn West's capital expenditure levels, production, operating cost and G&A expenditures performance for 2016, including fluctuations in commodity prices and its ongoing asset disposition program.
All press releases are available on Penn West's website at www.pennwest.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Sensitivity Analysis
Estimated sensitivities to selected key assumptions on funds flow from operations for the 12 months subsequent to the date of this MD&A, including risk management contracts entered to date, are based on forecasted results as discussed in the Outlook above.
Impact on cash flow | |||
Change of: |
Change |
$ millions |
$/share |
Price per barrel of liquids |
$1.00 |
4 |
0.01 |
Liquids production |
1,000 bbls/day |
17 |
0.03 |
Price per mcf of natural gas |
$0.10 |
2 |
- |
Natural gas production |
10 mmcf/day |
6 |
0.01 |
Effective interest rate |
1% |
3 |
0.01 |
Exchange rate ($US per $CAD) |
$0.01 |
1 |
- |
Contractual Obligations and Commitments
Penn West is committed to certain payments over the next five calendar years and thereafter as follows:
2016 |
2017 |
2018 |
2019 |
2020 |
Thereafter | |||||||
Long-term debt |
$ |
450 |
$ |
26 |
$ |
32 |
$ |
341 |
$ |
36 |
$ |
27 |
Transportation |
3 |
13 |
9 |
7 |
6 |
8 | ||||||
Power infrastructure |
4 |
14 |
8 |
8 |
8 |
6 | ||||||
Drilling rigs |
5 |
7 |
- |
- |
- |
- | ||||||
Interest obligations |
8 |
20 |
18 |
8 |
2 |
2 | ||||||
Office lease (1) |
8 |
35 |
35 |
35 |
35 |
143 | ||||||
Decommissioning liability (2) |
$ |
9 |
$ |
17 |
$ |
20 |
$ |
19 |
$ |
18 |
$ |
127 |
(1) |
The future office lease commitments above are to be reduced by contracted sublease recoveries totalling $115 million. |
(2) |
These amounts represent the inflated, discounted future reclamation and abandonment costs that are expected to be incurred over the life of the Company's properties. |
The Company's syndicated bank facility is due for renewal on May 6, 2019. In addition, the Company has an aggregate of US$106 million in senior notes maturing between 2016 and 2025, after the offer to holders of the Company's senior notes was subsequently prepaid in October 2016. If the Company is unsuccessful in renewing or replacing the syndicated bank facility or obtaining alternate funding for some or all of the maturing amounts of the senior notes, it is possible that it could be required to obtain other facilities, including term bank loans.
The Company is involved in various litigation and claims in the normal course of business and records provisions for claims as required.
In February 2016, Penn West announced it had entered agreements to settle all class action proceedings in Canada and United States against the Company related to damages alleged to have been incurred due to a decline in Penn West's share price following the announcement in 2014 that the Company would need to restate certain of its historical financial statements and related MD&A. The settlement agreements provide for a payment of $53 million split evenly between Canadian and US investors that is fully funded by insurance coverage maintained by Penn West. As a result, the payment will not impact the Company's cash or financial position. The proposed settlements have received required court approval in each of Alberta, Ontario and Quebec and in New York, and all conditions to settlement have been satisfied. As a result of the approval of these settlements, there is no further exposure to the Company.
Equity Instruments
Common shares issued: |
||
As at September 30, 2016 |
502,543,988 | |
Stock option plan |
51,400 | |
As at November 1, 2016 |
502,595,388 | |
Options outstanding: |
||
As at September 30, 2016 |
10,655,875 | |
Exercised |
(51,400) | |
Forfeited |
(480,500) | |
As at November 1, 2016 |
10,123,975 |
Changes in Internal Control Over Financial Reporting ("ICFR")
Penn West's senior management has evaluated whether there were any changes in the Company's ICFR that occurred during the period beginning on July 1, 2016 and ending on September 30, 2016 that have materially affected, or are reasonably likely to materially affect, the Company's ICFR. No changes to Penn West's ICFR were made during the quarter.
Penn West utilizes the original Internal Control - Integrated Framework (2013) issued by the Committee of the Sponsoring Organizations of the Treadway Commission (COSO) to design and evaluate its internal control over financial reporting.
Future Accounting Pronouncements
The IASB issued IFRS 15 "Revenue from Contracts with Customers" which replaces IAS 18 "Revenue". IAS 15 specifies revenue recognition criteria and expanded disclosures for revenue. The new standard is effective for annual periods beginning on or after January 1, 2018 and early adoption is permitted. Penn West is currently assessing the impact of the standard.
The IASB completed the final sections of IFRS 9 "Financial Instruments" which replaces IAS 39 "Financial Statement: Recognition and Measurement". IFRS 9 provides guidance on the recognition and measurement, impairment and derecognition on financial instruments. The new standard is effective for annual periods beginning on or after January 1, 2018 and early adoption is permitted. Penn West is currently assessing the impact of the standard.
The IASB issued IFRS 16 "Leases" in January 2016 which replaces IAS 17 "Leases". IFRS 16 outlines several new requirements in regards to the recognition, measurement and disclosure of leases. A key principle within the standard includes a single lessee accounting model which requires lessees to recognise assets and liabilities for all leases which have a term more than 12 months. The accounting for lessors, which classify leases as either operating or finance, remains substantially unchanged from the previous standard. The new standard is effective for annual reporting periods beginning on or after 1 January 2019. Penn West is currently assessing the impact of the standard.
Off-Balance-Sheet Financing
The Company has off-balance-sheet financing arrangements consisting of operating leases. The operating lease payments are summarized in the "Contractual Obligations and Commitments section" of this MD&A.
Non-GAAP Measures
Certain financial measures including funds flow from operations, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues included in this MD&A do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow from operations is cash flow from operating activities before changes in non-cash working capital and decommissioning expenditures which also excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is representative of cash related to continuing operations. Funds flow from operations is used to assess the Company's ability to fund dividend and planned capital programs. See "Calculation of Funds Flow from Operations" above for a reconciliation of funds flow from operations to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Results of Operations – Netbacks" above for a calculation of the Company's netbacks. EBITDA is Cash Flow from Operations excluding the impact of changes in non-cash working capital, decommissioning expenditures, financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. EBITDA as defined by Penn West's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Penn West's covenant calculations related to its syndicated bank facility and senior notes. Gross revenue is total revenues including realized risk management gains and losses on commodity contracts and is used to assess the cash realizations on commodity sales.
Oil and Gas Information
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: under "Business Strategy", that the Company expects to remain in compliance with all its financial covenants for the foreseeable future, that the Company will continue to streamline its asset portfolio and focus its operations within the Cardium, Viking and Peace River areas in Alberta, by disposing of properties outside of its core areas the Company anticipates a lower cost structure in both unit operating costs and abandonment liabilities, that within the core area, the Company believes its asset base will grow reserves, increase organic production, and increase funds flow from operations under the current commodity price environment; under "Results of Operations – Production", that the two drilled wells in the Cardium, one in Peace River and 11 within the Alberta Viking will all be completed in fourth quarter of 2016; that the Company has deferred a number of discretionary expenses, primarily turnarounds and workover activities, to later in the year resulting in the Company maintaining its annual operating cost per boe target; under "General and Administrative Expenses", anticipated range for G&A per boe for 2016; under "Restructuring Expense", that the Company requires less office space in the future, as the Company continues to progress through its disposition strategy and reduces its headcount, further restructuring expenses will be incurred, that the Company plans to focus on capital activities within its core areas in the Cardium, Viking and Peace River all within Alberta; under "Capital Expenditures"; that capital activities in the fourth quarter of 2016 will be focused on completion and tie-in of these wells in addition to further drilling within the Cardium and Peace River, that the Company will continue to advance on its disposition initiatives in the fourth quarter of 2016; under "Environmental and Climate Change", our belief that compliance with environmental legislation could require additional expenditures and a failure to comply with such legislation may result in fines and penalties which could, in the aggregate and under certain assumptions, become material, our intent to reduce the environmental impact from our operations through environmental programs; under "Outlook", the additional dispositions anticipated for the fourth quarter, the annual corporate production guidance range, average production from core area properties, exploration and development capital expenditures and decommissioning expenditures; operating costs range per boe and G&A per boe range for 2016; and under "Sensitivity Analysis", the estimated sensitivities to selected key assumptions on funds flow for the 12 months subsequent to this MD&A. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future.
With respect to forward-looking statements contained in this document, the Company has made assumptions regarding, among other things: that the Company does not dispose of additional material producing properties or royalties or other interests therein; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; and the continued suspension of our dividend.
Although the Company believes that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that the Company will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that the Company anticipates will accrue to our Company and our security holders as a result of the successful execution of such plan do not materialize; the possibility that the Company is unable to execute some or all of our ongoing asset disposition program on favorable terms or at all; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, the Company does not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Additional Information
Additional information relating to Penn West, including Penn West's Annual Information Form, is available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
Penn West Petroleum Ltd. | |||||||
(CAD millions, unaudited) |
Note |
September 30, 2016 |
December 31, 2015 | ||||
Assets |
|||||||
Current |
|||||||
Cash |
6 |
$ |
447 |
$ |
2 | ||
Accounts receivable |
93 |
154 | |||||
Other |
26 |
42 | |||||
Deferred funding asset |
3 |
75 |
63 | ||||
Risk management |
8 |
15 |
44 | ||||
656 |
305 | ||||||
Non-current |
|||||||
Deferred funding asset |
3 |
29 |
168 | ||||
Exploration and evaluation assets |
4 |
146 |
243 | ||||
Property, plant and equipment |
5 |
3,118 |
5,145 | ||||
Risk management |
8 |
- |
63 | ||||
3,293 |
5,619 | ||||||
Total assets |
$ |
3,949 |
$ |
5,924 | |||
Liabilities and Shareholders' Equity |
|||||||
Current |
|||||||
Accounts payable and accrued liabilities |
$ |
138 |
$ |
380 | |||
Current portion of long-term debt |
6 |
469 |
222 | ||||
Provisions |
7 |
36 |
21 | ||||
Risk management |
8 |
3 |
3 | ||||
646 |
626 | ||||||
Non-current |
|||||||
Long-term debt |
6 |
443 |
1,718 | ||||
Provisions |
7 |
282 |
376 | ||||
Risk management |
8 |
19 |
- | ||||
Deferred tax liability |
77 |
266 | |||||
Other non-current liabilities |
4 |
3 | |||||
1,471 |
2,989 | ||||||
Shareholders' equity |
|||||||
Shareholders' capital |
9 |
8,996 |
8,994 | ||||
Other reserves |
97 |
92 | |||||
Deficit |
(6,615) |
(6,151) | |||||
2,478 |
2,935 | ||||||
Total liabilities and shareholders' equity |
$ |
3,949 |
$ |
5,924 |
See accompanying notes to the unaudited interim consolidated financial statements. |
Subsequent events (Notes 6 and 12)
Commitments and contingencies (Note 11)
Penn West Petroleum Ltd. | ||||||||||
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(CAD millions, except per share amounts, unaudited) |
Note |
2016 |
2015 |
2016 |
2015 | |||||
Oil and natural gas sales and other income |
$ |
115 |
$ |
273 |
$ |
490 |
$ |
948 | ||
Royalties |
(6) |
(20) |
(17) |
(96) | ||||||
109 |
253 |
473 |
852 | |||||||
Risk management gain |
8 |
28 |
104 |
10 |
142 | |||||
137 |
357 |
483 |
994 | |||||||
Expenses |
||||||||||
Operating |
55 |
159 |
227 |
474 | ||||||
Transportation |
7 |
12 |
29 |
35 | ||||||
General and administrative |
14 |
23 |
43 |
68 | ||||||
Restructuring |
7 |
111 |
22 |
122 |
27 | |||||
Share-based compensation |
10 |
4 |
(4) |
11 |
3 | |||||
Depletion, depreciation and impairment |
4,5 |
131 |
989 |
607 |
1,344 | |||||
Loss (gain) on dispositions |
5 |
2 |
1 |
(30) |
(94) | |||||
Exploration and evaluation |
4 |
1 |
2 |
7 |
2 | |||||
Foreign exchange loss (gain) |
6 |
19 |
104 |
(86) |
257 | |||||
Financing |
6 |
22 |
40 |
103 |
120 | |||||
Accretion |
7 |
4 |
9 |
18 |
28 | |||||
Impairment of goodwill |
- |
22 |
- |
22 | ||||||
Deferred funding asset |
3 |
82 |
- |
82 |
- | |||||
452 |
1,379 |
1,133 |
2,286 | |||||||
Loss before taxes |
(315) |
(1,022) |
(650) |
(1,292) | ||||||
Deferred tax recovery |
(83) |
(258) |
(186) |
(252) | ||||||
Net and comprehensive loss |
$ |
(232) |
$ |
(764) |
$ |
(464) |
$ |
(1,040) | ||
Net loss per share |
||||||||||
Basic |
$ |
(0.46) |
$ |
(1.52) |
$ |
(0.92) |
$ |
(2.07) | ||
Diluted |
$ |
(0.46) |
$ |
(1.52) |
$ |
(0.92) |
$ |
(2.07) | ||
Weighted average shares outstanding (millions) |
||||||||||
Basic |
9 |
502.3 |
502.2 |
502.2 |
501.9 | |||||
Diluted |
9 |
502.3 |
502.2 |
502.2 |
501.9 |
See accompanying notes to the unaudited interim consolidated financial statements. |
Penn West Petroleum Ltd. | ||||||||||
Three months ended September 30 |
Nine months ended September 30 | |||||||||
(CAD millions, unaudited) |
Note |
2016 |
2015 |
2016 |
2015 | |||||
Operating activities |
||||||||||
Net loss |
$ |
(232) |
$ |
(764) |
$ |
(464) |
$ |
(1,040) | ||
Depletion, depreciation and impairment |
4,5 |
131 |
989 |
607 |
1,344 | |||||
Impairment of goodwill |
- |
22 |
- |
22 | ||||||
Gain on dispositions |
5 |
- |
- |
(39) |
(97) | |||||
Exploration and evaluation |
4 |
1 |
2 |
7 |
2 | |||||
Accretion |
7 |
4 |
9 |
18 |
28 | |||||
Deferred tax recovery |
(83) |
(258) |
(186) |
(250) | ||||||
Share-based compensation |
10 |
2 |
1 |
6 |
3 | |||||
Restructuring |
7 |
106 |
- |
108 |
- | |||||
Unrealized risk management loss (gain) |
8 |
2 |
(76) |
111 |
(1) | |||||
Unrealized foreign exchange loss (gain) |
6 |
(94) |
89 |
(235) |
162 | |||||
Deferred funding asset |
3 |
82 |
- |
82 |
- | |||||
Decommissioning expenditures |
7 |
(1) |
(9) |
(5) |
(25) | |||||
Change in non-cash working capital |
(16) |
54 |
(103) |
- | ||||||
(98) |
59 |
(93) |
148 | |||||||
Investing activities |
||||||||||
Capital expenditures |
5 |
(13) |
(116) |
(32) |
(371) | |||||
Property dispositions, net |
76 |
(1) |
1,401 |
411 | ||||||
Change in non-cash working capital |
6 |
20 |
(40) |
(123) | ||||||
69 |
(97) |
1,329 |
(83) | |||||||
Financing activities |
||||||||||
Increase (decrease) in long-term debt |
6 |
(7) |
23 |
(127) |
507 | |||||
Repayments of senior notes |
6 |
(634) |
(84) |
(814) |
(664) | |||||
Realized foreign exchange loss on repayments |
6 |
113 |
15 |
149 |
95 | |||||
Issue of equity |
9 |
1 |
- |
1 |
- | |||||
Dividends paid |
- |
(5) |
- |
(70) | ||||||
(527) |
(51) |
(791) |
(132) | |||||||
Change in cash |
(556) |
(89) |
445 |
(67) | ||||||
Cash, beginning of period |
1,003 |
89 |
2 |
67 | ||||||
Cash, end of period |
$ |
447 |
$ |
- |
$ |
447 |
$ |
- |
See accompanying notes to the unaudited interim consolidated financial statements. |
Penn West Petroleum Ltd. | |||||||||
(CAD millions, unaudited) |
Note |
Shareholders' |
Other Reserves |
Deficit |
Total | ||||
Balance at January 1, 2016 |
$ |
8,994 |
$ |
92 |
$ |
(6,151) |
$ |
2,935 | |
Net and comprehensive loss |
- |
- |
(464) |
(464) | |||||
Share-based compensation |
10 |
- |
6 |
- |
6 | ||||
Issue on exercise of options |
9 |
2 |
(1) |
- |
1 | ||||
Balance at September 30, 2016 |
$ |
8,996 |
$ |
97 |
$ |
(6,615) |
$ |
2,478 | |
Note |
Shareholders' |
Other Reserves |
Deficit |
Total | |||||
(CAD millions, unaudited) | |||||||||
Balance at January 1, 2015 |
$ |
8,983 |
$ |
89 |
$ |
(3,490) |
$ |
5,582 | |
Net and comprehensive loss |
- |
- |
(1,040) |
(1,040) | |||||
Share-based compensation |
10 |
- |
3 |
- |
3 | ||||
Issued to dividend reinvestment plan |
9 |
10 |
- |
- |
10 | ||||
Dividends declared |
9 |
- |
- |
(15) |
(15) | ||||
Balance at September 30, 2015 |
$ |
8,993 |
$ |
92 |
$ |
(4,545) |
$ |
4,540 |
See accompanying notes to the unaudited interim consolidated financial statements. |
Notes to the Unaudited Consolidated Financial Statements
(All tabular amounts are in CAD millions except numbers of common shares, per share amounts,
percentages and various figures in Note 8)
1. Structure of Penn West
Penn West Petroleum Ltd. ("Penn West" or the "Company") is an exploration and production company and is governed by the laws of the Province of Alberta, Canada. The Company operates in one segment, to explore for, develop and hold interests in oil and natural gas properties and related production infrastructure in the Western Canada Sedimentary Basin directly and through investments in securities of subsidiaries holding such interests. Penn West's portfolio of assets is managed at an enterprise level, rather than by separate operating segments or business units. The Company assesses its financial performance at the enterprise level and resource allocation decisions are made on a project basis across Penn West's portfolio of assets, without regard to the geographic location of projects. Penn West owns the petroleum and natural gas assets or 100 percent of the equity, directly or indirectly, of the entities that carry on the remainder of the oil and natural gas business of Penn West, except for an unincorporated joint arrangement (the "Peace River Oil Partnership") in which Penn West's wholly owned subsidiaries hold a 55 percent interest.
Penn West operates under the trade names of Penn West and Penn West Exploration.
2. Basis of presentation and statement of compliance
a) Basis of Presentation
The interim consolidated financial statements include the accounts of Penn West, its wholly owned subsidiaries and its proportionate interest in partnerships. Results from acquired properties are included in Penn West's reported results subsequent to the closing date and results from properties sold are included until the closing date.
All intercompany balances, transactions, income and expenses are eliminated on consolidation.
Certain comparative figures have been reclassified to correspond with current period presentation.
b) Statement of Compliance
These unaudited condensed interim consolidated financial statements ("interim consolidated financial statements") are prepared in compliance with IAS 34 "Interim Financial Reporting" and accordingly do not contain all of the disclosures included in Penn West's annual audited consolidated financial statements.
The interim consolidated financial statements were prepared using the same accounting policies, critical accounting judgments and key estimates as in the annual consolidated financial statements as at and for the year ended December 31, 2015.
All tabular amounts are in millions of Canadian dollars, except numbers of common shares, per share amounts, percentages and other figures as noted.
The interim consolidated financial statements were approved for issuance by the Board of Directors on November 1, 2016.
3. Deferred funding assets
Deferred funding amounts relate to Penn West's share of capital and operating expenses to be funded by Penn West's partner in the Peace River Oil Partnership and Penn West's share of capital expenditures to be funded by Penn West's partner in the Cordova Joint Venture. Amounts expected to be settled within the next 12 months are classified as current.
September 30, 2016 |
December 31, 2015 | |||
Peace River Oil Partnership |
$ |
104 |
$ |
149 |
Cordova Joint Venture |
- |
82 | ||
Total |
$ |
104 |
$ |
231 |
Current portion |
$ |
75 |
$ |
63 |
Long-term portion |
29 |
168 | ||
Total |
$ |
104 |
$ |
231 |
During the third quarter of 2016, the Company impaired the deferred funding asset related to the Cordova Joint Venture located in British Columbia as it no longer has future plans for development in the area.
4. Exploration and evaluation ("E&E") assets
Nine months ended |
Year ended December 31, 2015 | |||
Balance, beginning of period |
$ |
243 |
$ |
505 |
Capital expenditures |
- |
10 | ||
Expense |
(7) |
(7) | ||
Impairment |
(89) |
(252) | ||
Transfers to PP&E |
(1) |
(13) | ||
Balance, end of period |
$ |
146 |
$ |
243 |
During the third quarter of 2016, the Company impaired certain natural gas properties located within British Columbia as it no longer has future plans for development in this area. The Company plans to focus on its core areas in the Cardium, Viking and Peace River all within Alberta. The E&E impairment recorded during the period totaled $37 million ($51 million before-tax).
During the first quarter of 2016, the Company entered into signed sales agreements to dispose of certain properties and recorded a $27 million E&E impairment ($38 million before-tax) as a result of classifying certain assets as assets held for sale. These transactions subsequently closed in April 2016.
5. Property, plant and equipment ("PP&E")
Cost |
Nine months ended |
Year ended December 31, 2015 | ||
Balance, beginning of period |
$ |
16,210 |
$ |
17,456 |
Capital expenditures |
32 |
460 | ||
Joint venture, carried capital |
23 |
31 | ||
Acquisitions |
- |
7 | ||
Dispositions |
(5,008) |
(1,539) | ||
Transfers from E&E |
1 |
13 | ||
SR&ED tax credits |
(3) |
(29) | ||
Net decommissioning dispositions |
(200) |
(189) | ||
Balance, end of period |
$ |
11,055 |
$ |
16,210 |
Accumulated depletion and depreciation |
Nine months ended |
Year ended December 31, 2015 | ||
Balance, beginning of period |
$ |
11,065 |
$ |
9,550 |
Depletion and depreciation |
295 |
667 | ||
Impairments |
223 |
1,700 | ||
Dispositions |
(3,646) |
(852) | ||
Balance, end of period |
$ |
7,937 |
$ |
11,065 |
Net book value |
September 30, 2016 |
December 31, 2015 | ||
Total |
$ |
3,118 |
$ |
5,145 |
The Company made significant progress on its asset disposition initiatives during 2016 as it closed its Saskatchewan Viking disposition for total proceeds of approximately $975 million and its Slave Point properties for total proceeds of approximately $148 million, both subject to closing adjustments. Additionally, a number of minor, non-core property dispositions were closed during the year. In 2016, Penn West recorded gains on dispositions of $30 million (2015 - $94 million), which included $9 million of transaction costs, primarily related to advisory fees (2015 - $3 million).
During the third quarter of 2016, the Company recorded $13 million of PP&E impairment ($18 million before-tax) on certain natural gas properties located in British Columbia as they were recorded at the lesser of fair value less costs to sell and their carrying amount.
In the second quarter of 2016, the Company recorded $81 million of PP&E impairment ($111 million before-tax) as a result of classifying certain assets as assets held for sale. This value was based on the proceeds from signed sales agreements that the Company entered into during July 2016, which subsequently closed during the third quarter of 2016. In the first quarter of 2016, the Company entered into signed sales agreements to dispose of certain properties and recorded a $69 million PP&E impairment ($94 million before-tax) as a result of classifying certain assets as assets held for sale. These transactions subsequently closed in April 2016.
Impairments have been recorded as Depletion, Depreciation and Impairment on the Statement of Loss.
6. Long-term debt
Amount (millions) |
Maturity |
Average interest |
September 30, 2016 |
December 31, 2015 | |||
2007 Notes |
US$92 |
2017 – 2022 |
6.86% |
$ |
121 |
$ |
268 |
2008 Notes |
US$103, CAD$14 |
2018 – 2020 |
7.30% |
149 |
492 | ||
UK Notes |
£16 |
2018 |
6.95% (2) |
27 |
71 | ||
2009 Notes |
US$20 (3), £7, €3 |
2019 |
9.83% (4) |
42 |
126 | ||
2010 Q1 Notes |
US$71 |
2017 – 2025 |
6.68% |
93 |
205 | ||
2010 Q4 Notes |
US$58, CAD$13 |
2017 – 2025 |
5.94% |
89 |
195 | ||
2011 Notes |
US$36, CAD$8 |
2016 – 2021 |
5.49% |
55 |
121 | ||
Total senior secured notes |
576 |
1,478 | |||||
Syndicated bank facility advances |
336 |
462 | |||||
Total long-term debt |
$ |
912 |
$ |
1,940 | |||
Current portion |
$ |
469 |
$ |
222 | |||
Long-term portion |
$ |
443 |
$ |
1,718 |
(1) |
Average interest rate can fluctuate based on debt to EBITDA ratio which expires on March 30, 2017, the date the covenant relief period ends with the bank syndicate and noteholders. |
(2) |
These notes currently bear interest at 7.95 percent in Pounds Sterling, however, contracts were entered to fix the interest rate at 6.95 percent in Canadian dollars and to fix the exchange rate on the repayment (refer to Note 8). |
(3) |
A portion of the 2009 Notes have equal repayments, which began in 2013 with a repayment of US$5 million, and extend over the remaining years. |
(4) |
The Company entered into contracts to fix the interest rate on the Pounds Sterling and Euro tranches, at 10.15 percent and 10.22 percent, to 9.15 percent and 9.22 percent, respectively, and to fix the exchange rate on repayment (refer to Note 8). |
In the first nine months of 2016, the Company prepaid senior notes in aggregate of $627 million (2015 - $358 million) and a total of $340 million (2015 – $56 million) of indebtedness was repaid under the Company's syndicated bank facility.
In September 2016, the Company offered an additional $448 million of net proceeds received from dispositions during the year for prepayment of outstanding senior notes. The offer to holders of the Company's senior notes was substantially accepted and $437 million was subsequently prepaid in October 2016. The remaining $11 million was used to repay indebtedness on the Company's syndicated bank facility.
Including the payments in October, in 2016 the Company has completed prepayments to its lenders totalling $1,415 million (2015 - $414 million) which includes prepayments of senior notes of $1,064 million (2015 - $358 million) and repayments of indebtedness under the Company's syndicated bank facility of $351 million (2015 – $56 million).
Additionally, during 2016 Penn West repaid senior notes in an aggregate of US$141 million (2015 - US$193 million and CAD$50 million) as part of normal course maturities.
There were no senior note issuances in either 2016 or 2015.
Additional information on Penn West's senior notes is as follows:
September 30, 2016 |
December 31, 2015 | |||
Weighted average remaining life (years) |
2.7 |
3.1 | ||
Weighted average interest rate (1) |
6.9% |
7.6% |
(1) Includes the effect of cross currency swaps (refer to Note 8). |
At September 30, 2016, the Company had a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion maturing on May 6, 2019. The syndicated bank facility contains provisions for stamping fees on bankers' acceptances and LIBOR loans and standby fees on unutilized credit lines that vary depending on certain financial ratios. At September 30, 2016, the Company had $848 million of unused credit capacity available.
Drawings on the Company's bank facility are subject to fluctuations in short-term money market rates as they are generally held as short-term borrowings. At September 30, 2016, 37 percent (December 31, 2015 – 24 percent) of Penn West's long-term debt instruments were exposed to changes in short-term interest rates.
At September 30, 2016, letters of credit totalled $16 million (December 31, 2015 – $49 million). Letters of credit reduce the available borrowing capacity under the syndicated bank facility.
Penn West records unrealized foreign exchange gains or losses on its senior notes as amounts are translated into Canadian dollars at the rate of exchange in effect at the balance sheet. The split between realized and unrealized foreign exchange is as follows:
Three months ended September 30 |
Nine months ended September 30 | |||||||
2016 |
2015 |
2016 |
2015 | |||||
Realized foreign exchange loss on debt maturities |
$ |
- |
$ |
- |
$ |
(36) |
$ |
(36) |
Realized foreign exchange loss on debt pre-payments |
(113) |
(15) |
(113) |
(59) | ||||
Unrealized foreign exchange gain (loss) |
94 |
(89) |
235 |
(162) | ||||
Foreign exchange gain (loss) |
$ |
(19) |
$ |
(104) |
$ |
86 |
$ |
(257) |
The Company is subject to certain financial covenants under its syndicated bank facility and senior notes. These types of financial covenants are typical for senior lending arrangements and include senior debt and total debt to EBITDA and Senior Debt and Total Debt to Capitalization, as more specifically defined in the applicable lending agreements. At September 30, 2016, the Company was in compliance with all of its financial covenants under such lending agreements.
In May 2015, the Company finalized amending agreements with the lenders under its syndicated bank facility and with the holders of its senior notes to, among other things, amend its financial covenants as follows:
The Company also agreed to the following:
7. Provisions
September 30, 2016 |
December 31, 2015 | |||
Decommissioning liability |
$ |
210 |
$ |
397 |
Office lease provision |
108 |
- | ||
Total |
$ |
318 |
$ |
397 |
Current portion |
$ |
36 |
$ |
21 |
Long-term portion |
282 |
376 | ||
Total |
$ |
318 |
$ |
397 |
Decommissioning liability
The decommissioning liability was determined by applying an inflation factor of 2.0 percent (December 31, 2015 – 2.0 percent) and the inflated amount was discounted using a credit-adjusted rate of 7.5 percent (December 31, 2015 – 7.5 percent) over the expected useful life of the underlying assets, currently extending over 50 years into the future.
Changes to the decommissioning liability were as follows:
Nine months ended September 30, 2016 |
Year ended December 31, 2015 | |||
Balance, beginning of period |
$ |
397 |
$ |
585 |
Net liabilities disposed (1) |
(186) |
(61) | ||
Decrease in provision due to change in estimate |
(14) |
(128) | ||
Liabilities settled |
(5) |
(36) | ||
Accretion charges |
18 |
37 | ||
Balance, end of period |
$ |
210 |
$ |
397 |
Current portion |
$ |
21 |
$ |
21 |
Long-term portion |
$ |
189 |
$ |
376 |
(1) Includes additions from drilling activity, facility capital spending and disposals related to net property dispositions. |
Office lease provision
Due to the Company closing several significant asset dispositions in 2016 which reduced the size of its operations, Penn West recognized a provision related to certain office lease commitments as these are considered to be onerous contracts. The provision totaled $108 million (2015 – nil) and represents the present value of the future lease payments that the Company is obligated to make under non-cancellable lease contracts less recoveries under current sub-lease agreements. The cash flows have been discounted using Penn West's credit-adjusted rate of 7.5 percent. This estimate may vary as a result of future changes in estimated recoveries.
At September 30, 2016, $15 million was classified as current (December 31, 2015 – nil) and $93 million has been classified as non-current (December 31, 2015 – nil).
8. Risk management
Financial instruments consist of accounts receivable, fair values of derivative financial instruments, accounts payable and accrued liabilities, dividends payable and long-term debt. Except for the senior notes described in Note 6, the fair values of these financial instruments approximate their carrying amounts due to the short-term maturity of the instruments, the mark to market values recorded for the financial instruments and the market rate of interest applicable to the syndicated bank facility. At September 30, 2016, the estimated fair values of the principal and interest obligations of the outstanding notes totalled $523 million (December 31, 2015 – $1.4 billion) compared to the carrying value of $576 million (December 31, 2015 – $1.5 billion).
The fair values of all outstanding financial, commodity, power, interest rate and foreign exchange contracts are reflected on the balance sheet with the changes during the period recorded in income as unrealized gains or losses.
As at September 30, 2016 and December 31, 2015, the only asset or liability measured at fair value on a recurring basis was the risk management asset and liability, which was valued based on "Level 2 inputs" being quoted prices in markets that are not active or based on prices that are observable for the asset or liability.
The following table reconciles the changes in the fair value of financial instruments outstanding:
Risk management asset (liability) |
Nine months ended September 30, 2016 |
Year ended December 31, 2015 | |||
Balance, beginning of period |
$ |
104 |
$ |
114 | |
Unrealized gain (loss) on financial instruments: |
|||||
Commodity collars, swaps and assignments |
(41) |
13 | |||
Electricity swaps |
2 |
6 | |||
Foreign exchange forwards |
(43) |
(47) | |||
Cross currency swaps |
(29) |
18 | |||
Total fair value, end of period |
$ |
(7) |
$ |
104 |
Penn West had the following financial instruments outstanding as at September 30, 2016. Fair values are determined using external counterparty information, which is compared to observable market data. Penn West limits its credit risk by executing counterparty risk procedures which include transacting only with institutions within Penn West's syndicated bank facility or companies with high credit ratings and by obtaining financial security in certain circumstances.
Notional |
Remaining Term |
Pricing |
Fair value | |||
Natural gas |
||||||
AECO Swaps |
14,000 mcf/d |
Oct/16 – Dec/16 |
$3.05/mcf |
$ |
1 | |
AECO Swaps |
4,700 mcf/d |
Oct/16 – Dec/16 |
$2.69/mcf |
- | ||
AECO Swaps |
15,000 mcf/d |
Jan/17 – Mar/17 |
$3.03/mcf |
- | ||
AECO Swaps |
13,200 mcf/d |
Apr/17 – Jun/17 |
$2.70/mcf |
- | ||
AECO Swaps |
11,300 mcf/d |
Jul/17 – Sep/17 |
$2.71/mcf |
- | ||
AECO Swaps |
9,400 mcf/d |
Oct/17 – Dec/17 |
$3.00/mcf |
- | ||
AECO Swaps |
1,900 mcf/d |
Jan/17 – Dec/17 |
$2.92/mcf |
- | ||
AECO Swaps |
3,800 mcf/d |
Jan/18 – Dec/18 |
$2.89/mcf |
- | ||
Crude Oil |
||||||
WTI Swaps |
3,000 bbl/d |
Oct/16 – Dec/16 |
$64.58/bbl |
- | ||
WTI Swaps |
5,000 bbl/d |
Oct/16 – Dec/16 |
$72.08/bbl |
5 | ||
WTI Swaps |
3,000 bbl/d |
Jan/17 – Mar/17 |
$69.37/bbl |
1 | ||
WTI Swaps |
3,500 bbl/d |
Jan/17 – Dec/17 |
$66.07/bbl |
(1) | ||
Electricity swaps |
||||||
Alberta Power Pool |
25 MW |
Oct/16 – Dec/16 |
$49.90/MWh |
(2) | ||
Foreign exchange forwards on senior notes |
||||||
3 to 15-year initial term |
US$25 |
2017 |
1.000 CAD/USD |
8 | ||
Cross currency swaps |
||||||
10-year initial term |
£57 |
2018 |
2.0075 CAD/GBP, 6.95% |
(17) | ||
10-year initial term |
£20 |
2019 |
1.8051 CAD/GBP, 9.15% |
(1) | ||
10-year initial term |
€10 |
2019 |
1.5870 CAD/EUR, 9.22% |
(1) | ||
Total |
$ |
(7) |
Based on September 30, 2016 pricing, a $1.00 change in the price per barrel of liquids would have changed pre-tax unrealized risk management by $3 million and a $0.10 change in the price per mcf of natural gas would change pre-tax unrealized risk management by $1 million.
The components of risk management on the Statement of Loss are as follows:
Three months ended September 30 |
Nine months ended September 30 | ||||||||
2016 |
2015 |
2016 |
2015 | ||||||
Realized |
|||||||||
Settlement of commodity contracts/assignment |
$ |
21 |
$ |
22 |
$ |
84 |
$ |
29 | |
Monetization of commodity contracts |
- |
- |
2 |
18 | |||||
Settlement of foreign exchange contracts |
9 |
6 |
3 |
31 | |||||
Monetization of foreign exchange contracts |
- |
- |
32 |
63 | |||||
Total realized risk management gain |
30 |
28 |
121 |
141 | |||||
Unrealized |
|||||||||
Commodity contracts |
(5) |
48 |
(41) |
6 | |||||
Electricity swaps |
- |
(3) |
2 |
4 | |||||
Crude oil assignment |
- |
4 |
- |
(3) | |||||
Foreign exchange contracts |
4 |
20 |
(43) |
(23) | |||||
Cross-currency swaps |
(1) |
7 |
(29) |
17 | |||||
Total unrealized risk management gain (loss) |
(2) |
76 |
(111) |
1 | |||||
Risk management gain |
$ |
28 |
$ |
104 |
$ |
10 |
$ |
142 |
Operating costs for the third quarter of 2016 included a realized loss of $1 million (2015 – $6 million) and for the nine months ended September 30, 2016 included a realized loss of $5 million (2015 – $10 million) on electricity contracts.
Market risks
Penn West is exposed to normal market risks inherent in the oil and natural gas business, including, but not limited to, commodity price risk, foreign currency rate risk, credit risk, interest rate risk and liquidity risk. The Company seeks to mitigate these risks through various business processes and management controls and from time to time by using financial instruments.
There have been no significant changes to these risks from those discussed in Penn West's annual audited consolidated financial statements.
Foreign currency rate risk
In 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes. At September 30, 2016, the following foreign currency forward contracts were outstanding:
Nominal Amount |
Settlement date |
Exchange rate |
Buy US$25 |
2017 |
1.000 CAD/USD |
9. Shareholders' equity
i) Issued
Shareholders' capital |
Common Shares |
Amount | |
Balance, January 1, 2015 |
497,320,087 |
$ |
8,983 |
Issued on exercise of equity compensation plans (1) |
- |
1 | |
Issued to dividend reinvestment plan |
4,843,076 |
10 | |
Balance, December 31, 2015 |
502,163,163 |
8,994 | |
Issued on exercise of equity compensation plans (1) |
381,000 |
2 | |
Cancellation of dividend reinvestment plan (2) |
(175) |
- | |
Balance, September 30, 2016 |
502,543,988 |
$ |
8,996 |
(1) Upon exercise of options, the net benefit is recorded as a reduction of other reserves and an increase to shareholders' capital. |
(2) In March 2016, the Company cancelled its dividend reinvestment plan. |
ii) Earnings per share - Basic and Diluted
The weighted average number of shares used to calculate per share amounts was as follows:
Three months ended September 30 |
Nine months ended September 30 | ||||
Average shares outstanding (millions) |
2016 |
2015 |
2016 |
2015 | |
Basic and Diluted |
502.3 |
502.2 |
502.2 |
501.9 |
For the third quarter of 2016, 10.7 million shares (2015 – 16.1 million) that would be issued under the Stock Option Plan ("Option Plan") were excluded in calculating the weighted average number of diluted shares outstanding as they were considered anti-dilutive.
For the first nine months of 2016, 10.7 million shares (2015 – 16.1 million) that would be issued under the Option Plan were excluded in calculating the weighted average number of diluted shares outstanding as they were considered anti-dilutive.
10. Share-based compensation
Stock Option Plan
Penn West has an Option Plan that allows Penn West to issue options to acquire common shares to officers, employees and other service providers.
Under the terms of the plan the number of options reserved for issuance under the Option Plan shall not exceed 4.25 percent of the aggregate number of issued and outstanding common shares of Penn West. The grant price of options is equal to the volume-weighted average trading price of the common shares on the TSX for a five-trading-day period immediately preceding the date of grant. Options granted to date vest over a four-year period and expire five years after the date of grant.
Nine months ended September 30, 2016 |
Year ended December 31, 2015 | |||||
Options |
Number of |
Weighted Average Exercise Price |
Number of |
Weighted | ||
Outstanding, beginning of period |
10,595,728 |
$ |
10.21 |
14,460,158 |
$ |
13.91 |
Granted |
3,557,250 |
1.20 |
5,122,600 |
1.85 | ||
Exercised |
(381,000) |
1.38 |
- |
- | ||
Forfeited/ Expired |
(3,116,103) |
15.05 |
(8,987,030) |
11.39 | ||
Outstanding, end of period |
10,655,875 |
$ |
6.11 |
10,595,728 |
$ |
10.21 |
Exercisable, end of period |
4,003,863 |
$ |
10.89 |
3,907,426 |
$ |
17.21 |
A Black-Scholes option-pricing model was used to determine the fair value of options granted under the Option Plan with the following fair value per option and weighted average assumptions:
Nine months ended September 30 | ||||
2016 |
2015 | |||
Average fair value of options granted (per share) |
$ |
0.54 |
$ |
0.63 |
Expected life of options (years) |
4.0 |
4.0 | ||
Expected volatility (average) |
61.0% |
43.6% | ||
Risk-free rate of return (average) |
0.6% |
0.6% | ||
Dividend yield |
nil |
2.0% |
Restricted Share Unit ("RSU") plan
Penn West has a RSU plan whereby Penn West employees receive consideration that fluctuates based on Penn West's share price on the TSX. Eligible employees receive a grant of a specific number of units (each of which notionally represents a common share) that vest over a three-year period. In March 2016, the Board approved that the consideration can now be paid in either cash or shares at their discretion on new grants. The Company believes that future consideration will be in the form of shares purchased on the open market at prevailing market prices. Consideration on all previous grants prior to March 2016 will continue to be paid in cash.
If the service requirements are met, the cash consideration paid is based on the number of units vested and the five-day weighted average trading price of the common shares prior to the vesting date plus dividends declared by Penn West during the period preceding the vesting date. If the consideration is provided in shares, each outstanding RSU would be exchanged for one common share.
As consideration can now be in the form of cash or shares, all grants subsequent to March 2016 will be accounted for based on the equity method.
RSU plan (number of shares equivalent) |
Nine months ended September 30, 2016 |
Year ended |
Outstanding, beginning of period |
6,325,954 |
3,166,476 |
Granted |
11,402,290 |
9,156,290 |
Vested |
(2,285,935) |
(1,281,077) |
Forfeited |
(4,158,967) |
(4,715,735) |
Outstanding, end of period |
11,283,342 |
6,325,954 |
Outstanding – liability method |
2,652,202 |
6,325,954 |
Outstanding – equity method |
8,631,140 |
- |
The fair value of the RSU plan units under the equity method used the following weighted average assumptions:
Nine months ended September 30 | ||||
2016 |
2015 | |||
Average fair value of units granted (per unit) |
$ |
1.21 |
$ |
- |
Expected life of units (years) |
3.0 |
- | ||
Expected forfeiture rate |
18.9% |
- |
At September 30, 2016, RSU plan obligations of $2 million were classified as a current liability (December 31, 2015 – $3 million) included in accounts payable and accrued liabilities and $2 million was classified as a non-current liability (December 31, 2015 – $2 million) included in other non-current liabilities.
Deferred Share Unit ("DSU") plan
The DSU plan allows Penn West to grant DSUs in lieu of cash fees to non-employee directors providing a right to receive, upon retirement, a cash payment based on the volume-weighted-average trading price of the common shares on the TSX for the five trading days immediately prior to the day of payment. Management directors are not eligible to participate in the DSU plan. At September 30, 2016, 700,851 DSUs (December 31, 2015 – 457,398) were outstanding and $1 million was recorded as a current liability (December 31, 2015 – $1 million).
Performance Share Unit ("PSU") plan
The PSU plan allows Penn West to grant PSUs to employees of Penn West. Upon meeting the vesting conditions, the employee could receive a cash payment based on performance factors determined by the Board of Directors and the share price. Members of the Board of Directors are not eligible for the PSU Plan.
PSU awards (number of shares equivalent) |
Nine months ended September 30, 2016 |
Year ended |
Outstanding, beginning of period |
1,622,881 |
771,020 |
Granted |
2,316,000 |
1,483,000 |
Vested |
(199,844) |
(294,567) |
Forfeited |
(391,037) |
(336,572) |
Outstanding, end of period |
3,348,000 |
1,622,881 |
The PSU obligation is classified as a liability due to the cash settlement feature. The change in the fair value of outstanding PSU awards is charged to income based on the common share price at the end of each reporting period plus accumulated dividends multiplied by a performance factor determined by the Board of Directors. At September 30, 2016, $1 million was classified as a current liability (December 31, 2015 – nil) and included in accounts payable and accrued liabilities and $2 million was classified as a non-current liability (December 31, 2015 – $1 million) and included in other non-current liabilities.
Share-based compensation
Share-based compensation is based on the fair value of the options and units at the time of grant under the Option Plan and RSU plan (equity method), which is amortized over the remaining vesting period on a graded vesting schedule. Share-based compensation under the RSU plan (liability method), DSU and PSU is based on the fair value of the awards outstanding at the reporting date and is amortized based on a graded vesting schedule. Share-based compensation consisted of the following:
Nine months ended September 30 | ||||
2016 |
2015 | |||
Options |
$ |
2 |
$ |
3 |
RSU plan – liability method |
3 |
- | ||
RSU plan – equity method |
4 |
- | ||
PSU |
2 |
- | ||
Share-based compensation |
$ |
11 |
$ |
3 |
The share price used in the fair value calculation of the RSU plan (liability method), PSU and DSU obligations at September 30, 2016 was $2.35 (September 30, 2015 – $0.60). Share-based compensation related to the DSU was insignificant in both periods.
Employee retirement savings plan
Penn West has an employee retirement savings plan (the "savings plan") for the benefit of all employees. Under the savings plan, employees may elect to contribute up to 10 percent of their salary and Penn West matches these contributions at a rate of $1.50 for each $1.00 of employee contribution. Both the employee's and Penn West's contributions are used to acquire Penn West common shares or are placed in low-risk investments. Shares are purchased in the open market at prevailing market prices.
11. Commitments and contingencies
The Company is involved in various litigation and claims in the normal course of business and records provisions for claims as required.
In February 2016, Penn West announced it had entered agreements to settle all class action proceedings in Canada and United States against the Company related to damages alleged to have been incurred due to a decline in Penn West's share price following the announcement in 2014 that the Company would need to restate certain of its historical financial statements and related MD&A. The settlement agreements provide for a payment of $53 million split evenly between Canadian and US investors that is fully funded by insurance coverage maintained by Penn West. As a result, the payment will not impact the Company's cash or financial position. The proposed settlements have received required court approval in each of Alberta, Ontario and Quebec and in New York, and all conditions to settlement have been satisfied. As a result of the approval of these settlements, there is no further exposure to the Company.
12. Subsequent event
In September 2016, the Company offered $448 million of net proceeds received from dispositions during the year for prepayment of outstanding senior notes. The offer to holders of the Company's senior notes was substantially accepted and $437 million was subsequently pre-paid in October 2016. The remaining $11 million was used to repay indebtedness on the Company's syndicated bank facility in October 2016.
SOURCE Penn West
CALGARY, Oct. 14, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is expected to release its third quarter 2016 financial and operating results on Wednesday, November 2, 2016 before North American markets open. The third quarter 2016 management's discussion and analysis and unaudited consolidated financial statements will be available on the Company's website at www.pennwest.com, on SEDAR at http://www.sedar.com and on EDGAR at www.sec.gov.
A presentation will accompany the conference call and will be available via the webcast. Alternatively, the presentation will be made available immediately prior to the conference call start time of 9:00 am Mountain Time on Penn West's website at: http://www.pennwest.com/investors/presentations-webcasts
CONFERENCE CALL & WEBCAST DETAILS
A conference call and webcast presentation will be held to discuss the matters noted above at 9:00 am Mountain Time (11:00 am Eastern Time) on Wednesday, November 2, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1281273&s=1&k=28EA646FAFFFE0BE427BB3122083F436
A digital recording will be available for replay two hours after the call's completion, and will remain available until November 16, 2016 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 93554835, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, Oct. 4, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is pleased to announce that David French will be joining the company as President and Chief Executive Officer and will join the Board of Directors with effect from October 24, 2016 succeeding Dave Roberts who has been in the role since June, 2013.
Mr. French, 47, most recently served as President and CEO of Bankers Petroleum Ltd., a Calgary-based publicly-traded oil and gas company with operations in Southeastern Europe. Mr. French successfully led the operational and commercial growth of the enterprise over his tenure. He has worked a wide range of reservoir rock types, and primary, secondary and tertiary development throughout Canada, the lower 48 United States and Europe. Prior to joining Bankers in 2013, Mr. French held several executive roles at Apache Corporation including Regional Production Manager for the western Canadian business, and Global Vice President of Business Development. Earlier in his career Mr. French worked for McKinsey & Co. in energy consulting and built his career in the Permian Basin for Amoco Production Company (now BP). Mr. French holds a Bachelor's degree in mechanical engineering from Rice University and an MBA from Harvard Business School.
"I am thrilled to have this opportunity to join Penn West and help deliver the promise of our new core business. This is an exciting time for the company as we focus on the future and build an engine for growth", says Mr. French. "Penn West has an enviable position in the Cardium play that is enjoying a technological renaissance through well completion design and application of water flooding, and there are exciting opportunities in the Alberta Viking that I expect to provide attractive investment options. I look forward to joining the team at Penn West as we focus on setting the standard for what's possible in our assets."
Rick George, Chairman of the Penn West board comments "We are extremely pleased to have David French join us as our new CEO. David has the right combination of technical, executive management and business development skills to lead Penn West in its evolution into a best in class light oil growth company with a solid balance sheet."
Mr. Roberts will continue to lead Penn West in October working with Mr. French and the Board of Directors to ensure a seamless leadership transition.
In commenting on the transition, Mr. George said, "For the past three years Dave Roberts has brought his broad industry experience, energy, and a tremendous will to the reshaping and repositioning of Penn West. He is leaving us with a highly focused company and a strong talented team. Dave also had the vision to begin discussing with the Board some time ago the need for the smaller, more nimble "new" Penn West to have new leadership to take it forward into the future. We are grateful to Dave for his service during a time of extremely difficult industry conditions."
Mr. Roberts added, "People have said that we could write a book about our experience over the past three years here, but words couldn't capture the affection I have for the people of Penn West who never lost heart and never quit on our journey. Penn West is on solid footing with a sensible balance sheet, very good oil growth assets and importantly, a deep and talented team of people in all facets of the company from our management team to our technical disciplines, support functions, and critically, our field operations personnel. I look forward to watching David and the Penn West team take the baton and surge forward to a bright future."
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that Mr. French will join the company as President and Chief Executive Officer and the Board of Directors with effect from October 24, 2016 and that Mr. Roberts will continue to lead Penn West in October working with Mr. French and the Board of Directors to ensure a seamless leadership transition.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document as there can be no assurances that the plans, intentions, or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could affect Penn West, or its operations or financial results, are included in the Company's public filings with applicable securities regulatory authorities (including our Annual Information Form), which may be accessed in Canada at www.sedar.com and in the United States at www.sec.gov . Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, Oct. 3, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") announces that it has offered $448 million of cash on hand to its senior noteholders to prepay amounts owing to them at par and on a pro rata basis. The total principal amount of the senior notes currently outstanding is approximately $576 million prior to the prepayment offer. We expect to complete the prepayment process prior to releasing our third quarter financial and operating results in early November.
The $448 million of cash is from previously announced asset sales completed this year, not including the sale of all of our Saskatchewan assets, with the most recent asset sales representing proceeds of approximately $75 million completed in the third quarter. The agreements with our senior noteholders allow us to use asset sale proceeds to make prepayment offers to them at par.
We expect our pro-forma Senior Debt at the end of the third quarter to be reduced to approximately $470 million from $2.0 billion at year-end 2015 and our Senior Debt to EBITDA to be 2.0 times relative to a 4.5 times covenant threshold which is within the top half of our peers. We also expect to remain in full compliance with all of our financial covenants going forward into 2017. In the event the prepayment offer is not fully accepted by our noteholders, we intend to use the unallocated cash to reduce the amount outstanding under our revolving bank credit facility.
"Our decision to apply the asset sale proceeds towards our notes reduces the effective interest rate on our debt and advances our goal of continuing to simplify Penn West's debt capital structure", David Dyck, Senior Vice President and Chief Financial Officer of Penn West commented. "We would like to thank all of our lenders for their patience and support as we have worked diligently to transform our company. Our successful asset divesture program has provided us with the balance sheet strength and financial flexibility to proceed with a balanced development plan in our core areas. Our refocused asset base is very competitive, with a top quartile cost base and a compelling organic growth profile."
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our expectation to complete the prepayment process prior to releasing our third quarter financial and operating results, our expectation for year-end pro-forma Senior Debt levels and Senior Debt to EBITDA ratio, our expectation that we will remain in full compliance with all of our financial covenants going forward into 2017, our intention to use any unallocated cash to reduce the outstanding amount under our revolving bank facility, and our successful asset divestiture program having provided us with the balance sheet strength and financial flexibility to proceed with a balanced development plan in our core areas.
The forward-looking statements are based on certain key expectations and assumptions made by Penn West. Although Penn West believes that the expectations and assumptions on which such forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking information because Penn West can give no assurances that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks.
Additional information on these and other factors that could affect Penn West, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein) , Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Penn West's website.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, July 26, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE) ("Penn West", "we", "us" or "our") is expected to release its second quarter 2016 financial and operating results on Thursday, August 4, 2016 before North American markets open. The second quarter 2016 management's discussion and analysis and unaudited consolidated financial statements will be available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
A presentation will accompany the conference call and will be available via the webcast. Alternatively, the presentation will be made available immediately prior to the conference call start time of 9:00 am Mountain Time on Penn West's website at: http://www.pennwest.com/investors/presentations-webcasts
CONFERENCE CALL & WEBCAST DETAILS
A conference call and webcast presentation will be held to discuss the matters noted above at 9:00 am Mountain Time (11:00 am Eastern Time) on Thursday, August 4, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1227225&s=1&k=457F15D57D0452CCBB474A66CC24EF0E
A digital recording will be available for replay two hours after the call's completion, and will remain available until August 18, 2016 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 51571011, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE"
SOURCE Penn West
CALGARY, July 4, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") is pleased to announce that it received notification from the New York Stock Exchange (the "NYSE") that it has regained compliance with the NYSE's Continued listing standard regarding the price of its common stock.
On January 4, 2016, Penn West received notification from the NYSE that Penn West had fallen below the NYSE's continued listing standard, which requires a minimum average closing price of US$1.00 over a consecutive 30 trading day period. Penn West regained compliance at the close of trading on June 30, 2016 since the average closing price of its common stock for the consecutive 30 trading days ended June 30, 2016 and the closing price of its common stock on June 30, 2016 both exceeded US$1.00.
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE".
SOURCE Penn West
CALGARY, June 24, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE.BC) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce that it has successfully closed the previously announced sale of all of its Saskatchewan assets for cash consideration of approximately $975 million, subject to closing adjustments. The Company will offer the net cash proceeds from the sale to its lenders and noteholders at par on a pro rata basis.
"This transaction marks a significant turning point for Penn West. We have worked tirelessly to achieve top-tier performance on all operating fronts in our core areas and now with our re-constituted balance sheet and capital structure we will move our leverage metrics to top tier status as well", David Dyck, Senior Vice President and Chief Financial Officer of Penn West commented. "We expect to be in full compliance with all of our financial covenants at the end of the second quarter and anticipate the removal of the going concern note from our financial statements in the near future. As the benefits of our improved capital structure become more visible to investors over the coming months, we believe the market will close the valuation gap in our stock price. With our past largely behind us and our prospects bright, Penn West is now a very compelling value proposition for investors."
We will continue to execute on the second phase of our asset disposition program over the coming months in order to high-grade our portfolio and continue to reduce our cost structure. We expect to provide an update of our ongoing plans along with second quarter financial results in early August 2016.
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the Company will offer the net cash proceeds from the sale to its lenders and noteholders at par on a pro rata basis, that our re-constituted balance sheet and capital structure will allow us to move our leverage metrics to top tier status, that we expect to be in full compliance with all of our financial covenants at the end of the second quarter and anticipate the removal of the going concern note from our financial statements in the near future, the belief that the market will close the valuation gap in our stock price once our improved capital structure becomes more visible to investors over the coming months, that we will continue to execute on the second phase of our asset disposition program over the coming months in order to high-grade our portfolio and continue to reduce our cost structure, and we expect to provide and update of our ongoing plans along with second quarter financial results in early August 2016.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, June 23, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE.BC) ("Penn West" "or the Company") is pleased to announce that at its annual and special meeting of shareholders held on June 23, 2016, Penn West's shareholders approved all resolutions outlined in the Notice of 2016 Annual and Special Meeting and Management Proxy Circular dated May 10, 2016 (the "Information Circular"), which is available on SEDAR at www.sedar.com, on EDGAR at www.sec.gov, and on Penn West's website at www.pennwest.com.
1. Appointment of Auditor
By resolution passed by show of hands, Ernst & Young LLP, Chartered Accountants, was appointed as auditor of Penn West for the ensuing year.
2. Election of Directors
By resolutions passed by ballot vote, the following eight nominees proposed by management were elected as directors of the Company to hold office until the next annual meeting of Shareholders or until their successors are elected or appointed:
Name of Nominee
|
||||||
Votes For |
Percent |
Votes Withheld |
Percent | |||
George H. Brookman |
91.83 |
% |
8.17 |
% | ||
John Brydson |
92.49 |
% |
7.51 |
% | ||
Raymond D. Crossley |
92.25 |
% |
7.75 |
% | ||
William A. Friley |
92.09 |
% |
7.91 |
% | ||
Richard L. George |
90.82 |
% |
9.18 |
% | ||
Maureen Cormier Jackson |
92.15 |
% |
7.85 |
% | ||
David E. Roberts |
94.00 |
% |
6.00 |
% | ||
Jay W. Thornton |
90.65 |
% |
9.35 |
% |
3. Approval of Unallocated Options Pursuant to the Stock Option Plan
By resolution passed by ballot vote, all unallocated options to acquire common shares under the Company's stock option plan until June 23, 2019 were approved. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
88.27 |
% |
11.73 |
% |
4. Non-Binding Advisory Vote on the Corporation's Approach to Executive Compensation
By resolution passed by ballot vote, an advisory resolution was passed to approve the Company's approach to executive compensation as outlined in the Information Circular. The results of the ballot were as follows:
Votes For |
Percent |
Votes Withheld |
Percent |
87.80 |
% |
12.20 |
% |
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
SOURCE Penn West
CALGARY, June 21, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE.BC) ("Penn West", "we", "us" or "our") is pleased to announce that a notice has been issued under the Competition Act by the Commissioner of Competition granting clearance to Penn West and Teine Energy Ltd. to complete the previously announced sale of all of Penn West's Saskatchewan assets, including its Dodsland Viking area, for cash consideration of $975 million, subject to normal closing adjustments. This Competition Act clearance is the only regulatory approval needed to complete the sale.
Penn West also announces that the closing of the sale of its Saskatchewan assets is expected to occur on or about June 24, 2016. The completion of the sale remains subject to customary closing conditions. As a result, we expect to be fully in compliance with all of our financial covenants at the end of the second quarter and the remainder of 2016.
In addition, in connection with the previously announced Alberta asset dispositions for total proceeds of approximately $140 million, Penn West is pleased to announce that approximately $27 million of these asset dispositions have been completed, with the sales of the remaining approximately $113 million of assets expected to close on or about June 27, 2016, subject to customary closing conditions.
The total cash consideration from asset dispositions to date in 2016 is approximately $1.3 billion, reducing our pro forma Net Debt to approximately $600 million from $2.1 billion at year-end 2015.
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta. Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, that the sale of all of Penn West's Saskatchewan assets is expected to close on or before June 24, 2016, the expectation to be fully in compliance with all of our financial covenants at the end of second quarter and for the remainder of 2016, and that the sales of approximately $113 million of some of Penn West's Alberta assets are expected to close on or about June 27, 2016.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, June 16, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE.BC) ("Penn West") will be hosting its Annual and Special Meeting on Thursday, June 23, 2016 at 10:00 a.m. MDT (12:00 p.m. EDT) in the Kensington Boardroom of the Marriott Downtown Hotel, located at 110 - 9th Avenue SE, Calgary Alberta.
Scheduled as part of the meeting proceedings, Mr. Dave Roberts, President and CEO, will address shareholders and provide a summary of Penn West's 2015 accomplishments and discuss Penn West's 2016 transformation into a leading Alberta oil producer. This address will be available via audio webcast:
Date: Thursday, June 23, 2016
Time: Approximately 10:10 a.m. MDT (12:10 p.m. EDT)
Expected Duration: 10 - 20 minutes
Audio Webcast Link: http://event.on24.com/r.htm?e=1210774&s=1&k=4F4D6EB53ADA58A0EDAE0BC73C7E9F9A
A replay of the audio webcast will be available after the meeting on our website at www.pennwest.com
Electronic copies of our management proxy circular, financial statements, news releases, and other public information are available on our website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
SOURCE Penn West
Transforms Penn West Into A Leading Alberta Oil Producer
CALGARY, June 10, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE.BC) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce that it has entered into a definitive agreement for the sale of all of its Saskatchewan assets, including its Dodsland Viking area, for cash consideration of $975 million, subject to normal closing adjustments. The Saskatchewan assets are split approximately evenly between medium and heavy oil properties in the West and the Dodsland light-oil properties in the East. The purchaser is Teine Energy Ltd., a Viking producer backed by the Canada Pension Plan Investment Board.
This transaction, together with additional Alberta asset dispositions for proceeds of approximately $140 million, is expected to close in the second quarter. The total cash consideration from asset dispositions to date in 2016 is approximately $1.3 billion, reducing our pro forma Net Debt to approximately $600 million from $2.1 billion at year-end 2015. As a result, we expect to be comfortably in compliance with all of our financial covenants at the end of the second quarter and the remainder of 2016.
"Saskatchewan is a coveted asset amongst many of our competitors and with this transaction we have capitalized on the demand for high-quality oil assets of scale", David Dyck, Senior Vice President and Chief Financial Officer of Penn West commented. "This is a pivotal transaction for the Company. While we have made significant progress over the past three years in reducing our total debt, this asset sale results in a markedly improved capital structure and positions the Company in the top tier of our peers in terms of all significant debt metrics. Additionally, the sales metrics received are meaningfully above recent precedent transactions in the area and are very accretive to our shareholders."
We expect to realize nearly $100 million annually as a result of decreased interest expenses and significant reductions in G&A expenses through this transaction, which more than offsets the loss in net operating income associated with the Saskatchewan properties(1).
The following are some of the key metrics and implied transaction multiples for the Saskatchewan properties based on our full year 2016 forecast:
Production |
13,650 boe/d |
Operating Cost |
$14.75/boe |
Field Netback(1) |
$12.75/boe |
2P Reserves(2) |
53 MMboe |
Implied Production Multiple |
$71,400/boe/d |
Implied Net Operating Income (NOI) Multiple(1) |
15 times |
Implied 2P Reserves Multiple (2) |
$18.40/boe |
(1) Based on actual achieved commodity prices through May 2016 and C$60/bbl Edmonton Par for the balance of 2016 | |
(2) Based on year-end 2015 working interest reserves |
The effective date of the Saskatchewan assets sale is May 1, 2016 and closing is expected to occur in the second quarter, subject to the receipt of all necessary regulatory approvals and the satisfaction of closing conditions customary in transactions of this nature.
In addition to the sale of its Saskatchewan properties and through a series of transactions, Penn West sold other Alberta properties for proceeds of approximately $140 million with associated 2016 production of 3,100 boe/d.
RBC Capital Markets acted as our exclusive financial advisor on these transactions.
Corporate Update and Transformation to a Leading Alberta Oil Producer
The sale of our Saskatchewan assets is a key element of our transformation strategy allowing us to streamline and high-grade the remainder of our portfolio to once again grow reserves, production and funds flow from operations at a profitable and measured pace.
"While the Dodsland Viking was an important contributor to Penn West's growth profile in recent years, this transaction will allow us to replace these largely mature assets by funding the more prospective and numerous growth opportunities in our Cardium and Alberta Viking positions; areas where we are more focused and more competitive", commented Dave Roberts, President and Chief Executive Officer of Penn West. "We forecast that the combination of a concentrated asset portfolio, lower operating cost base, and reduced interest expense burden will allow us to grow the Company's production by approximately 10% annually well into the next decade, while still generating funds flow from operations in excess of our capital spending, at current commodity prices."
As we continue to monetize our non-core assets over the balance of the year, our remaining operations will be focused in Alberta as follows:
(3) Net of partner carried operating costs
We are continuing to rationalize a number of remaining non-core assets throughout the remainder of the year. We have a number of ongoing asset sale processes, at various stages of completion, and anticipate divesting these remaining high-cost, largely negative net operating income, properties by year-end. Total remaining production expected to be sold is approximately 20,000 boe/d with a range of values expected at $100 million to $200 million. Importantly, these transactions will also reduce the Company's well count by approximately 5,000 wells and our asset retirement obligation by $200 million.
"Three years ago Penn West embarked on a path to create the most competitive conventional oil producer in Western Canada. The journey was perhaps longer and more difficult than anyone expected as we have experienced the worst crude oil crash in over a decade. We persevered and we can now see the most challenging time in our Company's history coming to a close. As a result of our actions, we will have reduced debt by over $2.8 billion in the last three years, dramatically lowered our cost structure and meaningfully improved our operational execution. We are very excited to open a new chapter as our focused Alberta operations will create a top quartile Company with a strong and sustainable growth profile, operating costs of $10-$12/boe, and low leverage metrics", concluded Dave Roberts.
Our second half 2016 development program of $5-10 million is focused on the Peace River area, but we are actively monitoring opportunities to increase spending on optimization and base maintenance activities. We are also reviewing plans to ramp up spending and development activity in the second half of the year as commodity prices continue to strengthen. We will be formalizing our 2017 activity plans in the coming months to profitably grow our production and cash flows. We expect that we will be able to deliver a plan with improved efficiencies, lower costs, and meaningful reserve additions.
Guidance
We expect to provide updated corporate guidance and more details on our 2017 plan in the near future.
Conference Call and Webcast Details
A conference call and webcast presentation will be held to discuss the matters noted above at 10:00am MT (12:00pm ET) on Monday, June 13, 2016.
To listen to the conference call, please dial 647-427-7450 or 1-888-231-8191 (toll-free).
This call will be broadcast live on the Internet and may be accessed directly at the following URL: http://event.on24.com/r.htm?e=1207430&s=1&k=00666B2C392221137490F111C8534AA2
A digital recording will be available for replay two hours after the call's completion, and will remain available until June 24, 2016 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 28666425, followed by the pound (#) key.
About Penn West
Penn West is a conventional oil and natural gas producer in Canada. Our goal is to be the company that redefines oil and gas excellence in western Canada. Based in Calgary, Penn West operates a significant portfolio of opportunities with a dominant oil position in the Cardium, Viking and Peace River areas of Alberta.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our transformation into a leading Alberta oil producer, that the expected total cash consideration from asset sales (including the Saskatchewan assets) to date in 2016 to $1.3 billion, which reduces the pro forma Net Debt to approximately $600 million from $2.1 billion at year-end 2015, that the sale transaction is scheduled to close in the second quarter (subject to the receipt of all necessary regulatory approvals and the satisfaction of closing conditions customary in transactions of this nature), the expectation to be comfortably in compliance with all of our financial covenants for the second quarter and for the remainder of 2016, the expectation to realize nearly $100 million annually as a result of decreased interest expenses and significant reductions in G&A expenses through this transaction, which more that offsets the loss in net operating income associated with the Saskatchewan properties, the key metrics and implied transaction multiples for the Saskatchewan assets based on our full year 2016, forecast that the sale of our Saskatchewan production and reserve base is a key element or our transformation strategy allowing us to streamline and high-grade the remainder or our portfolio to once again grow reserves, production and funds flow from operations at a profitable and measured pace, that this transaction will allow us to replace mature assets by funding more prospective and numerous growth opportunities in our Cardium and Alberta Viking positions, areas where we are more focused and more competitive, the forecast that the combination of a concentrated asset portfolio, lower operating cost base, and reduced interest expense will allow us to grow the Company's production by approximately 10% annually well into the next decade, while still generating funds flow from operations in excess of our capital spending, at current commodity prices, our continuing to monetize our non-core assets over the balance of the year and focusing our remaining operations in Alberta with: (1) in Cardium, the expectation to continue driving profitable liquids growth through a combination of waterflood programs, infill drilling and new development for the foreseeable future and the execution of the sale transaction gives Penn West the financial flexibility to begin exploiting the multi horizon potential in our Cardium area and using the Belly River and Mannville formations to form part of our development strategy that we will be executing over the next several years; (2) in the Alberta Viking, seeing the opportunity to replicate our Dodsland experience, with similar strong economics, but with much higher growth potential given the early stage life cycle of the play, and the expectation that this area will be an important focus of our 2017 development program and a key growth area in the foreseeable future; and (3) in the Peace River area, our expectation that PROP will remain a stable production and cash generation vehicle for the Company, that larger scale thermal recovery, in a higher crude oil environment, would allow meaningful recovery of the significant oil potential in our Peace River acreage, our belief that most challenging time in our Company's history is coming to a close, that we will have reduced debt by over $2.8 billion in the last three years, dramatically lowered our cost structure and meaningfully improved our operational execution that our focused Alberta operations will create a top quartile Company with a strong and sustainable growth profile, operating costs of $10-12/boe, and low leverage metrics, our continuing to rationalize a number of remaining non-core assets throughout the remainder of the year, and anticipating divesting these remaining high-cost, largely negative net operating income, properties by year-end with total remaining production expected to be sold of approximately 20,000 boe/d with a range of values expected at $100 million to $200 million, that the transactions will reduce the Company's well count by approximately 5,000 wells and our asset retirement obligation by approximately $200 million, having the second half 2016 development program of $5-10 million focus on the Peace River Area but actively monitoring opportunities to increase spending on optimization and base maintenance activities, reviewing plans to ramp up spending and activity in the second half of the year as the commodity prices continue to strengthen and formalizing our 2017 plans in the coming months to profitably grow our production and cash flows, the expectation that we will be able to deliver a plan with improved efficiencies, lower costs and meaningful reserves additions and updated corporate guidance and more details on our 2017 activity plan in the near future.
The key metrics and implied transaction multiples for the Saskatchewan assets set forth in this press release may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information contained in this press release are based on assumptions about future events based on management's assessment of the relevant information currently available. In particular, this press release contains projected operational and financial information for 2016 for the Saskatchewan assets. The future-oriented financial information and financial outlooks contained in this press release have been approved by management as of the date of this press release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, May 16, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX – PWT; NYSE – PWE.BC) ("Penn West", the "Company", "we", "us" or "our") is pleased to announce its financial and operational results for the first quarter ended March 31, 2016. All figures are in Canadian dollars unless otherwise stated.
Three months ended March 31 | |||||||
2016 |
2015 |
% change | |||||
Financial (millions, except per share amounts) |
|||||||
Gross revenues (1,2) |
$ |
231 |
$ |
340 |
(32) | ||
Funds flow (2) |
89 |
112 |
(21) | ||||
Basic per share (2) |
0.18 |
0.22 |
(18) | ||||
Diluted per share (2) |
0.18 |
0.22 |
(18) | ||||
Funds flow from operations (2) |
47 |
77 |
(39) | ||||
Basic per share (2) |
0.09 |
0.15 |
(40) | ||||
Diluted per share (2) |
0.09 |
0.15 |
(40) | ||||
Net income (loss) |
(100) |
(248) |
(60) | ||||
Basic per share |
(0.20) |
(0.49) |
(59) | ||||
Diluted per share |
(0.20) |
(0.49) |
(59) | ||||
Capital expenditures (3) |
18 |
191 |
(91) | ||||
Long-term debt at period-end |
$ |
1,858 |
$ |
2,426 |
(23) | ||
Operations |
|||||||
Daily production |
|||||||
Light oil and NGL (bbls/d) |
40,572 |
52,448 |
(23) | ||||
Heavy oil (bbls/d) |
12,440 |
12,895 |
(4) | ||||
Natural gas (mmcf/d) |
144 |
177 |
(19) | ||||
Total production (boe/d) (4) |
77,010 |
94,905 |
(19) | ||||
Average sales price |
|||||||
Light oil and NGL (per bbl) |
$ |
34.49 |
$ |
46.11 |
(25) | ||
Heavy oil (per bbl) |
14.76 |
30.20 |
(51) | ||||
Natural gas (per mcf) |
$ |
1.96 |
$ |
3.08 |
(36) | ||
Netback per boe (4) |
|||||||
Sales price |
$ |
24.22 |
$ |
35.34 |
(31) | ||
Risk management gain (loss) |
5.75 |
3.44 |
67 | ||||
Net sales price |
29.97 |
38.78 |
(23) | ||||
Royalties |
(1.07) |
(4.30) |
(75) | ||||
Operating expenses (5) |
(13.02) |
(18.61) |
(30) | ||||
Transportation |
(1.63) |
(1.35) |
21 | ||||
Netback (2) |
$ |
14.25 |
$ |
14.52 |
(2) |
(1) |
Includes realized gains and losses on commodity contracts and excludes gains and losses on foreign exchange hedges. |
(2) |
The terms "gross revenues", "funds flow", "funds flow from operations" and their applicable per share amounts, and "netback" are non-GAAP measures. Please refer to the "Calculation of Funds Flow and Funds Flow from Operations" in the attached Management Discussion and Analysis and "Non-GAAP Measures" sections below. |
(3) |
Capital expenditures include costs related to Property, Plant and Equipment and Exploration and Evaluation. Includes the effect of capital carried by partners. |
(4) |
Please refer to the "Oil and Gas Information Advisory" section below for information regarding the term "boe". |
(5) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $4 million or $0.52 per boe (2015 - $3 million or $0.36 per boe). |
President's Message
During the first quarter of 2016, we continued to ride the momentum built in 2015 to deliver strong production volumes and execute on approximately $230 million of asset dispositions. Our operational performance exceeded expectations, as the initiatives completed over the last several years to improve production reliability and lower costs are being realized. We continue to work on capitalizing on our operational progress to date and strengthening our financial position for the future.
During the first quarter, operating results were better than anticipated with average production of 77,010 boe per day. The production was led by the continued strong performance in Cardium and Viking wells drilled in the fourth quarter. Additionally, our ongoing focus on reducing our costs and better run times through improved field operations across our asset base allowed us to economically produce volumes that had been earmarked for shut-in at budget time. These positive results demonstrate the effects of our streamlined culture that is focused on safety and operational excellence.
In the first quarter we entered into agreements for the sale of the Slave Point area, with associated 2016 production of 3,900 boe per day, for total proceeds of approximately $148 million, subject to closing conditions. We also disclosed the sale of other non-core assets for total proceeds of approximately $80 million, subject to closing conditions. Since the beginning of last year, we have now raised over $1 billion in cash proceeds from our disposition program.
We are engaged in discussions with our lenders to ensure that we have the necessary access to capital for the remainder of 2016 and beyond. These discussions are ongoing and we are targeting to have agreements with our lenders amending our financial covenants signed prior to the end of the second quarter. These amendments would be a key milestone and allow us to continue to focus on strengthening our balance sheet and reducing our debt levels.
The first quarter operating and general and administrative ("G&A") costs came in significantly under expectations at $13.02 per boe and $1.97 per boe, respectively. These cost savings are a result of several successful cost reduction initiatives, further re-alignment of our staff for anticipated activity levels and higher production. We also benefited from a lower than anticipated cost environment which meaningfully reduced costs in the last four months of 2015 below our accruals. We believe we are on track to meet our target to reduce our absolute operating costs by approximately 20 percent on a year over year, same field basis, which excludes the impact of dispositions, and to reduce our annual G&A costs by a further $15 to $20 million from the prior year.
During the first quarter we experienced the lowest crude oil and natural gas prices in over a decade. We were able to reduce the effect of this low pricing environment with our hedging program. We had approximately 25 percent of our crude oil production hedged at $73 per barrel and 15 percent of our natural gas production hedged at $3 per mcf. This program resulted in a $5.75 per boe increase to our corporate netbacks.
As a result of our operational performance in the first quarter, we are updating our 2016 full year guidance metrics. Our annual production guidance remains unchanged at 60,000 - 64,000 boe per day despite A&D activity announced year to date. We now expect our operating costs for the year to be between $17.00 - $18.00 per boe, down from $18.00 - $18.75 per boe. Our G&A target is unchanged for the year between $2.50 - $2.90 per boe.
Financial and Operational Highlights
Select Metrics in Core Areas
The table below outlines select metrics in our core areas for the three months ended March 31, 2016 and excludes the impact of hedging:
Area |
Select Metrics – Three Months Ended March 31, 2016 | ||||
Production |
Liquids Weighting |
Operating Cost |
Netback | ||
Cardium |
29,000 boe/d |
65% |
$11.00/boe |
$14.00/boe | |
Greater Viking |
19,500 boe/d |
87% |
$14.50/boe |
$9.50/boe | |
Total Core |
48,500 boe/d |
74% |
$12.50/boe |
$12.00/boe |
Operated Development Activity
Viking and Cardium
During the first quarter, Viking and Cardium activity was limited to completing and bringing on production from previously drilled wells with 21 wells and five wells brought on production, respectively.
In the Dodsland area of our Viking play, continued application of the 12 ton, 12 stage completion technique on the one-half mile laterals allowed additional cost reductions to be realized. Of the 21 wells brought online in the first quarter, eight were drilled and completed utilizing a one mile wellbore design, with the stabilized wells exhibiting production performance to date that is in excess of their respective type curves. We believe that this application of the one mile lateral design on our high-graded reservoir acreage will result in a reduction of our go-forward finding and development costs by 30 percent. We will continue to monitor the performance of these wells, but currently anticipate implementing this design, where supported by our land position, as we move forward with the expansion of our Viking play.
In the Cardium, we brought one well on production in the Crimson area and four wells in the J-lease area in the first quarter. Our Crimson wells drilled in the fourth quarter of last year continue to exceed expectations with production well above type curve. Waterflood implementation and design work is proceeding in our Crimson area.
Our current J-Lease program, including the wells brought on production in the second half of last year, continues to exceed our expectations with strong performance and low decline rates. Last year, our J-Lease program was impacted by infrastructure constraints in the area as we experienced several gas gathering line failures which restricted our production volumes. Accordingly, in the first quarter we replaced seven kilometers of the Station 8 pipeline to improve the reliability of the gas gathering system. This project was completed under budget and significantly ahead of schedule. The pipeline has generated positive results by increasing oil production by approximately 1,000 boe per day post repair, with several fourth quarter 2015 wells still being optimized.
In our J-Lease area, we continue to experience improved well performance as we moved from an open hole to a cemented sleeve liner system with slickwater fractures. We expect that the cemented liner system will improve waterflood performance and project economics through greater water injection control.
Peace River Oil Partnership ("PROP")
In collaboration with our joint venture partner, we are running a two rig program in the Peace River area this year. In the first quarter we drilled seven wells (3.9 net) and brought 10 wells (5.5 net) on production.
Over the past year we have improved our drill, complete, equipping and tie-in process consequently achieving significant improvements in cycle times. We have improved our spud to first production cycle time from 90 days to 14 days primarily through improved simultaneous operations. These changes have resulted in per well savings of approximately $1 million.
Approximately 90 percent of our working interest expenditures continue to be paid for by our partner in the PROP joint venture.
The table below provides a summary of our operational activity during the first quarter:
Number of Wells |
||||||||||||
Drilled |
Completed |
On production | ||||||||||
Gross |
Net |
Gross |
Net |
Gross |
Net | |||||||
Cardium |
0.0 |
0.0 |
1.0 |
1.0 |
5.0 |
5.0 | ||||||
Greater Viking |
0.0 |
0.0 |
15.0 |
15.0 |
21.0 |
21.0 | ||||||
PROP |
7.0 |
3.9 |
10.0 |
5.5 |
10.0 |
5.5 | ||||||
Total Core |
7.0 |
3.9 |
26.0 |
21.5 |
36.0 |
31.5 |
Senior Secured Debt
We continue to remain in compliance with all our financial covenants at March 31, 2016, including the Senior Debt to EBITDA covenant that was 4.4 times, relative to a 5.0 times limit. If the current low commodity price environment continues, we anticipate that we will not be able to certify, following the end of the second quarter, compliance with the Senior Debt to EBITDA or Total Debt to EBITDA financial covenants at June 30, 2016. We are engaged in discussions with our lenders with a view to entering into agreements to amend these financial covenants prior to the end of the second quarter of 2016, which if successful will mitigate the risk of default. In order to reduce the risk of default, we will continue to pursue our strategy of reducing absolute debt levels through further dispositions of assets and we will also continue to consider other options such as pursuing additional sources of capital from strategic investors. However, as there is a risk that the Company will not be in compliance with its financial covenants at the end of the second quarter of 2016 and there is no guarantee that the Penn West will be successful in negotiating amended financial covenants with its lenders or in pursuing other options, there is a risk of default under the Company's bank facility and noteholder agreements. This has resulted in uncertainty on the Company's ability to continue as a going concern.
The table below outlines the calculation of our Senior Debt to EBITDA covenant as at the end of the first quarter:
(millions, except ratios) |
Twelve months ended | |
Funds Flow |
$157 | |
Financing |
$165 | |
Realized gain on foreign exchange hedges on prepayments |
($18) | |
Realized foreign exchange loss – debt prepayments |
$123 | |
Restructuring expenses |
$37 | |
EBITDA |
$464 | |
EBITDA contribution from assets sold (1) |
($35) | |
EBITDA as defined by debt covenants |
$429 | |
Total senior notes |
$1,389 | |
Syndicated bank facility advances |
$469 | |
Total long-term debt |
$1,858 | |
Letters of credit – financial (2) |
$11 | |
Total senior debt |
$1,869 | |
Senior debt to EBITDA |
4.4x |
(1) |
Consists of EBITDA contributions from assets that have been disposed of in the prior 12 months. |
(2) |
Letters of credit that are classified as financial are included in the Senior debt calculation per the debt agreements. |
Updated Hedging Position
Our hedging program continues to help reduce the volatility of our funds flow from operations, and thereby improve our ability to align capital programs going forward. We target having hedges in place for approximately 25 percent to 40 percent of our crude oil exposure, net of royalties, and 40 percent to 50 percent of our gas exposure, net of royalties in the current year. We have not layered on additional hedges in response to low commodity prices experienced in the first quarter and preceding negotiations with lenders.
Our positions as of March 31, 2016 are as follows:
Q2 2016 |
Q3 2016 |
Q4 2016 |
Q1 2017 | ||
Oil Volume (bbl/d) |
7,000 |
6,000 |
6,000 |
3,000 | |
C$ WTI Price (C$/bbl) |
$70.98 |
$71.07 |
$71.24 |
$69.37 | |
Gas Volume (mmcf/d) |
19 |
19 |
19 |
||
AECO Price (C$/mcf) |
$2.96 |
$2.96 |
$2.96 |
Updated 2016 Guidance
We have reduced our operating expense guidance to $17.00 - $18.00/boe from $18.00 - $18.75/boe. Annual average production guidance remains unchanged despite dispositions announced year to date.
Our guidance for 2016 is as follows:
Metric |
Guidance Range | ||||||
Annual Average Production |
boe/d |
60,000 – 64,000 | |||||
Liquids Weighting |
% |
66 – 68 | |||||
E&D Capital Expenditures |
$ millions |
$50 | |||||
Decommissioning Expenditures |
$ millions |
$20 | |||||
Operating Costs |
$/boe |
$17.00 – 18.00 | |||||
G&A Costs |
$/boe |
$2.50 – $2.90 |
This guidance does not reflect any potential disposition activity.
We continue to focus our operational strategy based on current commodity price levels. Despite this focus, we believe our enterprise continues to offer significant torque to a potential recovery in oil prices as outlined in the following table:
FY 2016 |
Jan 15, 2016 ~US$33 WTI |
US$40 WTI |
US$45 WTI | |||||
Funds Flow from Operations |
$ millions |
$0 - $40 |
$80 - $120 |
$140 - $180 | ||||
EBITDA |
$ millions |
$155 - $195 |
$235 - $275 |
$295 - $335 |
All cases assume average 2016 AECO price of C$2.45 per mcf and average 2016 FX of C$1.45/US$.
Conference Call and Webcast Details
A conference call and webcast presentation will be held to discuss our first quarter results at 9:00am MT (11:00am ET) on Monday, May 16, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1185677&s=1&k=A0F472C7FAE5BBF7AD9D98F70F69BAD8
Additional Reader Advisories
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
This news release includes non-GAAP measures not defined under International Financial Reporting Standards ("IFRS") including funds flow, funds flow from operations, funds flow per share-basic, funds flow per share-diluted, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues. Such terms are explained under the heading "Non-GAAP Measures" in the attached Management's Discussion and Analysis. Non-GAAP measures do not have any standardized meaning prescribed by GAAP and therefore may not be comparable to similar measures presented by other issuers.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: under "President's Message", continuing to work on capitalization on operational progress to date and strengthening our financial position for the future, the positive results in Cardium and Viking demonstrate the effect of our streamlined culture that is focused on safety and operational excellence, targeting to have agreements with our lenders amending our financial covenants signed, that the amendments would be a key milestone and allow us to continue to focus on strengthening our balance sheet and reducing debt levels, our belief that we are on track to meet our target to reduce our absolute operating costs by approximately 20 percent on a year over year, same field basis, which excludes the impact of dispositions, and will reduce our annual G&A costs by a further $15 to $20 million from the prior year, maintaining or updating our 2016 full year guidance metrics (including annual production range, operating cost and G&A cost ranges per boe); under "Financial and Operational Highlights", maintaining our 2016 average production target, updating our operating cost per boe range, maintaining total expenditures guidance for 2016, maintaining G&A per boe range given that we anticipate lower production volumes later in the year; under "Operated Development Activity", the belief that the application of the one mile lateral design on our high-graded reservoir acreage will result in a reduction of our go-forward finding and development costs by 30 percent, continuing to monitor the performance of the wells in the Dodsland area and anticipating implement the lateral design, where supported by our land position, as we move forward with the expansion of our Viking play, continuing to experience improved well performance as we moved from an open hole to a cemented sleeve liner with slickwater fractures, the expectation that the cemented liner system will improve waterflood performance and project economics through greater water injection control; under "Senior Secured Debt", anticipating that we will not be able to certify following the end of the second quarter of 2016 if current low commodity price environment continues, compliance with the Senior Debt to EBITDA or Total Debt to EBITDA financial covenants at June 30, 2016, entering into amending agreements to amend the financial covenants prior to the end of the second quarter of 2016, which if successful will mitigate the risk of default, reducing the risk of default by continuing to pursue our strategy of reducing absolute debt levels through further dispositions of asset and considering other options such as pursuing additional sources of capital from strategic investors, the possible risk of default under the Company's bank facility and noteholder agreements and the resulting uncertainty on the Company's ability to continue as a going concern; under "Updated Hedging Positions", that our hedging program continues to help reduce the volatility of our funds flow from operations, and thereby improve our ability to align capital programs going forward, targeting certain hedges to be in place for our crude oil and gas exposure; under "Updated 2016 Guidance", the update or maintaining of the range for the annual average production guidance, liquids weighting, capital and decommissioning expenditures and expectations for our operation and G&A cost ranges, continuing to focus our operational strategy based on current commodity price levels and our belief that our enterprise continues to offer significant torque to a potential recovery in oil prices.
The forward-looking information is based on certain key expectations and assumptions made by Penn West, including expectations and assumptions concerning: prevailing and future commodity prices and currency exchange rates; applicable royalty rates and tax laws; interest rates; future well production rates and reserve volumes; operating costs; the timing of receipt of regulatory approvals; the performance of existing wells; the success obtained in drilling new wells; anticipated timing and results of capital expenditures; the sufficiency of budgeted capital expenditures in carrying out planned activities; the timing, location and extent of future drilling operations; the successful completion of acquisitions and dispositions; the availability and cost of labour and services; the state of the economy and the exploration and production business; the availability and cost of financing; and ability to market oil and natural gas successfully.
Although Penn West believes that the expectations and assumptions on which such forward-looking information is based are reasonable, undue reliance should not be placed on the forward-looking information because Penn West can give no assurances that they will prove to be correct. Since forward-looking information addresses future events and conditions, by its very nature it involves inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to: the risks associated with the oil and gas industry in general such as operational risks in development, exploration and production; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of estimates and projections relating to reserves, production, costs and expenses; health, safety and environmental risks; commodity price and exchange rate fluctuations; interest rate fluctuations; marketing and transportation; loss of markets; environmental risks; competition; incorrect assessment of the value of acquisitions; failure to complete or realize the anticipated benefits of acquisitions or dispositions; ability to access sufficient capital from internal and external sources; failure to obtain required regulatory and other approvals; reliance on third parties; and changes in legislation, including but not limited to tax laws, royalties and environmental regulations. Readers are cautioned that the foregoing list of factors is not exhaustive.
Additional information on these and other factors that could affect Penn West, or its operations or financial results, are included in the Company's most recently filed Management's Discussion and Analysis (See "Forward-Looking Statements" therein) , Annual Information Form (See "Risk Factors" and "Forward-Looking Statements" therein) and other reports on file with applicable securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Penn West's website.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
See also "Forward-Looking Statements" in the attached Management's Discussion and Analysis.
MANAGEMENT'S DISCUSSION AND ANALYSIS
For the three months ended March 31, 2016
This management's discussion and analysis of financial condition and results of operations ("MD&A") of Penn West Petroleum Ltd. ("Penn West", the "Company", "we", "us", "our") should be read in conjunction with the Company's unaudited interim condensed consolidated financial statements for the three months ended March 31, 2016 (the "Consolidated Financial Statements") and the Company's audited consolidated financial statements and MD&A for the year ended December 31, 2015. The date of this MD&A is May 13, 2016. All dollar amounts contained in this MD&A are expressed in millions of Canadian dollars unless noted otherwise.
Certain financial measures such as funds flow, funds flow from operations, funds flow per share-basic, funds flow per share-diluted, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues included in this MD&A do not have a standardized meaning prescribed by International Financial Reporting Standards ("IFRS") and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. This MD&A also contains oil and gas information and forward-looking statements. Please see the Company's disclosure under the headings "Non-GAAP Measures", "Oil and Gas Information", and "Forward-Looking Statements" included at the end of this MD&A.
Quarterly Financial Summary
(millions, except per share and production amounts)(unaudited)
Three months ended (1) |
Mar. 31 2016 |
Dec. 31 2015 |
Sep. 30 2015 |
June 30 2015 |
Mar. 31 2015 |
Dec. 31 2014 |
Sep. 30 2014 |
June 30 2014 | |||||||||
Gross revenues (2) |
$ |
231 |
$ |
273 |
$ |
295 |
$ |
360 |
$ |
340 |
$ |
473 |
$ |
589 |
$ |
656 | |
Funds flow from operations |
47 |
39 |
48 |
85 |
77 |
146 |
235 |
311 | |||||||||
Basic per share |
0.09 |
0.08 |
0.10 |
0.17 |
0.15 |
0.29 |
0.47 |
0.63 | |||||||||
Diluted per share |
0.09 |
0.08 |
0.10 |
0.17 |
0.15 |
0.29 |
0.47 |
0.63 | |||||||||
Funds flow |
89 |
7 |
14 |
47 |
112 |
137 |
231 |
298 | |||||||||
Basic per share |
0.18 |
0.01 |
0.03 |
0.09 |
0.22 |
0.28 |
0.47 |
0.61 | |||||||||
Diluted per share |
0.18 |
0.01 |
0.03 |
0.09 |
0.22 |
0.28 |
0.47 |
0.60 | |||||||||
Net income (loss) |
(100) |
(1,606) |
(764) |
(28) |
(248) |
(1,772) |
(15) |
143 | |||||||||
Basic per share |
(0.20) |
(3.20) |
(1.52) |
(0.06) |
(0.49) |
(3.57) |
(0.03) |
0.29 | |||||||||
Diluted per share |
(0.20) |
(3.20) |
(1.52) |
(0.06) |
(0.49) |
(3.57) |
(0.03) |
0.29 | |||||||||
Dividends declared |
- |
- |
5 |
5 |
5 |
70 |
69 |
69 | |||||||||
Per share |
$ |
- |
$ |
- |
$ |
0.01 |
$ |
0.01 |
$ |
0.01 |
$ |
0.14 |
$ |
0.14 |
$ |
0.14 | |
Production |
|||||||||||||||||
Liquids (bbls/d) (3) |
53,012 |
53,339 |
55,323 |
63,222 |
65,343 |
64,124 |
64,687 |
69,409 | |||||||||
Natural gas (mmcf/d) |
144 |
144 |
161 |
168 |
177 |
198 |
217 |
224 | |||||||||
Total (boe/d) |
77,010 |
77,398 |
82,198 |
91,164 |
94,905 |
97,143 |
100,839 |
106,706 |
(1) |
Certain comparative figures have been reclassified to correspond with current period presentation. |
(2) |
Includes realized gains and losses on commodity contracts and excludes gains and losses on foreign exchange hedges. |
(3) |
Includes crude oil and natural gas liquids. |
Calculation of Funds Flow and Funds Flow from Operations
Three months ended March 31 | ||||||
(millions, except per share amounts) |
2016 |
2015 | ||||
Cash flow from operating activities |
$ |
61 |
$ |
156 | ||
Change in non-cash working capital |
26 |
(55) | ||||
Decommissioning expenditures |
2 |
11 | ||||
Funds flow |
89 |
112 | ||||
Monetization of foreign exchange contracts |
(32) |
(44) | ||||
Settlements of normal course foreign exchange contracts |
- |
(2) | ||||
Monetization of transportation commitment |
(20) |
- | ||||
Realized foreign exchange loss – debt maturities |
- |
6 | ||||
Carried operating expenses (1) |
4 |
3 | ||||
Restructuring charges |
6 |
2 | ||||
Funds flow from operations |
$ |
47 |
$ |
77 | ||
Per share – funds flow |
||||||
Basic per share |
$ |
0.18 |
$ |
0.22 | ||
Diluted per share |
0.18 |
0.22 | ||||
Per share – funds flow from operations |
||||||
Basic per share |
0.09 |
0.15 | ||||
Diluted per share |
$ |
0.09 |
$ |
0.15 |
(1) |
The effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership. |
The decrease in funds flow compared to the prior quarter is mainly due to lower revenues as a result of a weaker commodity price environment and lower production volumes due to asset dispositions.
During the first quarter of 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes and it permanently disposed of a pipeline commitment it had and received $20 million of proceeds from the sale.
Business Strategy
During the first quarter of 2016, the Company continued to advance on its core strategies as it focuses on debt reduction and the long-term sustainability of the Company. All key targets came in ahead of expectations during the quarter as follows:
Penn West has made significant progress both operationally and financially over the past two years in an effort to strengthen its balance sheet. The Company will continue to seek improvements in its cost structure and its debt levels so that it is well positioned to move forward once commodity prices recover.
Business Environment
The following table outlines quarterly averages for benchmark prices and Penn West realized prices for the last five quarters.
Q1 2016 |
Q4 2015 |
Q3 2015 |
Q2 2015 |
Q1 2015 | |||||||
Benchmark prices |
|||||||||||
WTI crude oil ($US/bbl) |
$ |
33.45 |
$ |
42.18 |
$ |
46.43 |
$ |
57.94 |
$ |
48.63 | |
Edm mixed sweet par price (CAD$/bbl) |
40.67 |
52.85 |
56.17 |
67.93 |
51.76 | ||||||
NYMEX Henry Hub ($US/mcf) |
2.09 |
2.27 |
2.77 |
2.64 |
2.98 | ||||||
AECO Monthly Index (CAD$/mcf) |
1.97 |
2.56 |
2.85 |
2.66 |
2.95 | ||||||
Penn West average sales price (1) |
|||||||||||
Light oil (CAD$/bbl) |
37.44 |
50.20 |
52.60 |
64.56 |
49.82 | ||||||
Heavy oil (CAD$/bbl) |
14.76 |
25.40 |
31.20 |
46.44 |
30.20 | ||||||
NGL (CAD$/bbl) |
12.75 |
19.53 |
15.24 |
17.40 |
20.31 | ||||||
Total liquids (CAD$/bbl) |
29.86 |
42.16 |
44.83 |
55.85 |
42.97 | ||||||
Natural gas (CAD$/mcf) |
1.96 |
2.54 |
2.99 |
2.78 |
3.08 | ||||||
Benchmark differentials |
|||||||||||
WTI - Edm Light Sweet ($US/bbl) |
(3.69) |
(2.46) |
(3.42) |
(2.86) |
(6.80) | ||||||
WTI - WCS Heavy ($US/bbl) |
$ |
(14.24) |
$ |
(14.49) |
$ |
(13.27) |
$ |
(11.59) |
$ |
(14.73) |
(1) |
Excludes the impact of realized hedging gains or losses. |
Crude Oil
Crude oil prices continued to decline in the early part of the first quarter of 2016 as increased supply and weak demand moved prices below US$30 per barrel. Crude oil prices strengthened later in the quarter as major OPEC and non-OPEC countries discussed supply restrictions; however, this was tempered by continued high inventory levels.
Canadian light oil differentials weakened from the fourth quarter of 2015 averaging US$3.69 per barrel below WTI for the quarter. Heavy oil differentials traded within US$0.60 per barrel averaging US$14.24 below WTI for the quarter.
As at March 31, 2016, the Company has the following hedging positions in place:
Reference Price |
Term |
Price ($/Barrel) |
Volume (Barrels/day) | |||
WTI |
Apr 2016 – Dec 2016 |
CAD $72.08 |
5,000 | |||
WTI |
Apr 2016 – Jun 2016 |
CAD $68.25 |
2,000 | |||
WTI |
Jul 2016 – Sep 2016 |
CAD $66.05 |
1,000 | |||
WTI |
Oct 2016 – Dec 2016 |
CAD $67.05 |
1,000 | |||
WTI |
Jan 2017 – Mar 2017 |
CAD $69.37 |
3,000 |
Natural Gas
NYMEX Henry Hub natural gas prices continued their downward trend through the quarter as warm weather in key markets caused higher than average storage levels as the market approached the end of the withdrawal season. The Henry Hub prompt month price started the quarter at US$2.37 per MMBtu and ended trading for the quarter at US$1.96 per MMBtu averaging US$2.09 per MMBtu for the first quarter.
AECO pricing declined further compared to NYMEX as TCPL restrictions were lifted which resulted in additional production volumes in the market. High storage levels also contributed to further downward pressure on AECO prices. At the start of the first quarter the AECO Index price traded at $2.31 per mcf declining to $1.66 per mcf near the end of the quarter and AECO daily pricing averaging $1.33 per mcf in March.
Penn West had the following financial hedging positions in place for natural gas as at March 31, 2016.
Reference Price |
Term |
Price ($/mcf) |
Volume (mcf/day) | |||
AECO |
Apr 2016 – Dec 2016 |
CAD $3.05 |
14,000 | |||
AECO |
Apr 2016 – Dec 2016 |
CAD $2.69 |
4,700 |
Average Sales Prices
Three months ended March 31 | ||||||||
2016 |
2015 |
% change | ||||||
Light oil (per bbl) |
$ |
37.44 |
$ |
49.82 |
(25) | |||
Commodity gain (per bbl) (1) |
11.25 |
2.15 |
>100 | |||||
Light oil net (per bbl) |
48.69 |
51.97 |
(6) | |||||
Heavy oil (per bbl) |
14.76 |
30.20 |
(51) | |||||
NGL (per bbl) |
12.75 |
20.31 |
(37) | |||||
Natural gas (per mcf) |
1.96 |
3.08 |
(36) | |||||
Commodity gain (per mcf) (1) |
0.28 |
1.28 |
(78) | |||||
Natural gas net (per mcf) |
2.24 |
4.36 |
(49) | |||||
Weighted average (per boe) |
24.22 |
35.34 |
(31) | |||||
Commodity gain (per boe) (1) |
5.75 |
3.44 |
67 | |||||
Weighted average net (per boe) |
$ |
29.97 |
$ |
38.78 |
(23) |
(1) |
Realized risk management gains and losses on commodity contracts are included in gross revenues. |
RESULTS OF OPERATIONS
Production
Three months ended March 31 | |||||||||
Daily production |
2016 |
2015 |
% change | ||||||
Light oil (bbls/d) |
35,717 |
45,855 |
(22) | ||||||
Heavy oil (bbls/d) |
12,440 |
12,895 |
(4) | ||||||
NGL (bbls/d) |
4,855 |
6,593 |
(26) | ||||||
Natural gas (mmcf/d) |
144 |
177 |
(19) | ||||||
Total production (boe/d) |
77,010 |
94,905 |
(19) |
Production volumes were considerably ahead of the Company's expectations in the first quarter of 2016 primarily due to exceptional well performance in the Cardium and Viking areas. The Company has continued to experience production results on its second half 2015 development program significantly higher than type curve estimates. Additionally, a lower amount of production volumes were shut-in than previously anticipated which also contributed to the strong result. These factors have resulted in the Company maintaining its 2016 average production target of 60,000 – 64,000 per boe, after the effect of the property dispositions during the first quarter of 2016 and the Slave Point disposition that was closed in April 2016.
Penn West's production levels were lower than the comparative periods mainly due to non-core property dispositions that were closed in 2015 as the Company made progress on its planned disposition strategy and continued to reduce debt levels.
Netbacks
Three months ended March 31 | ||||||||||||
2016 |
2015 | |||||||||||
Light Oil and |
Heavy Oil |
Natural Gas |
Combined |
Combined | ||||||||
Operating netback: |
||||||||||||
Sales price (1) |
$ |
34.49 |
$ |
14.76 |
$ |
1.96 |
$ |
24.22 |
$ |
35.34 | ||
Commodity gain (2) |
9.90 |
- |
0.28 |
5.75 |
3.44 | |||||||
Royalties |
(2.68) |
(0.72) |
0.25 |
(1.07) |
(4.30) | |||||||
Transportation |
(1.19) |
(2.29) |
(0.34) |
(1.63) |
(1.35) | |||||||
Operating costs (3) |
(14.62) |
(14.76) |
(1.57) |
(13.02) |
(18.61) | |||||||
Netback |
$ |
25.90 |
$ |
(3.01) |
$ |
0.58 |
$ |
14.25 |
$ |
14.52 | ||
(bbls/d) |
(bbls/d) |
(mmcf/d) |
(boe/d) |
(boe/d) | ||||||||
Production |
40,572 |
12,440 |
144 |
77,010 |
94,905 |
(1) |
Excluded from the netback calculation in 2016 was $22 million of other income, mainly relating to the proceeds received by the Company from permanently disposing a pipeline commitment. |
(2) |
Realized risk management gains and losses on commodity contracts. |
(3) |
Includes the effect of carried operating expenses from the Company's partner under the Peace River Oil Partnership of $4 million or $0.52 per boe (2015 - $3 million or $0.36 per boe). |
During the first quarter of 2016, the Company's netbacks continued to be affected by the significant decreases in commodity prices, particularly heavy oil. This was partially offset by successful cost reduction initiatives which resulted in lower operating costs, increased commodity gains due to the Company's active hedging program and a reduction in royalties due to the lower commodity price environment.
Production Revenues
Revenues from the sale of oil, NGL and natural gas consisted of the following:
Three months ended March 31 | |||||||||
(millions) |
2016 |
2015 |
% change | ||||||
Light oil and NGL |
$ |
185 |
$ |
235 |
(21) | ||||
Heavy oil |
17 |
35 |
(51) | ||||||
Natural gas |
29 |
70 |
(59) | ||||||
Gross revenues (1) |
$ |
231 |
$ |
340 |
(32) |
(1) |
Includes realized risk management gain on commodity contracts which totaled $40 million for the three months ended March 31, 2016 (2015 - $29 million). |
Gross revenues have decreased from the comparative period as a result of a significant decrease in the commodity price environment and lower production volumes due to non-core asset dispositions that were closed in 2015. This was partially offset by the weakening of the Canadian dollar compared to the US dollar from the prior year.
Reconciliation of Change in Production Revenues
(millions) |
||||||
Gross revenues – January 1 – March 31, 2015 |
$ |
340 | ||||
Decrease in light oil and NGL production |
(16) | |||||
Decrease in light oil and NGL prices (1) |
(34) | |||||
Decrease in heavy oil production |
(1) | |||||
Decrease in heavy oil prices |
(17) | |||||
Decrease in natural gas production |
(13) | |||||
Decrease in natural gas prices (1) |
(28) | |||||
Gross revenues – January 1 – March 31, 2016 |
$ |
231 |
(1) |
Includes realized risk management gains and losses on commodity contracts. |
Royalties
Three months ended March 31 | ||||||||
2016 |
2015 |
% change | ||||||
Royalties (millions) |
$ |
7 |
$ |
37 |
(81) | |||
Average royalty rate (1) |
4% |
12% |
(8) | |||||
$/boe |
$ |
1.07 |
$ |
4.30 |
(75) |
(1) |
Excludes effects of risk management activities. |
Royalties have decreased from the comparative period primarily due to a decrease in the commodity price environment and the impact of asset disposition activity completed in 2015. Additionally during the first quarter of 2016, the Company settled outstanding royalty audits which resulted in the release of a $6 million provision that was no longer required. Excluding this impact the average royalty rate for the quarter would have been seven percent.
Expenses
Three months ended March 31 | ||||||||
(millions) |
2016 |
2015 |
% change | |||||
Operating |
$ |
95 |
$ |
162 |
(41) | |||
Transportation |
11 |
11 |
- | |||||
Financing |
40 |
37 |
8 | |||||
Share-based compensation |
$ |
3 |
$ |
- |
100 | |||
Three months ended March 31 | ||||||||
(per boe) |
2016 |
2015 |
% change | |||||
Operating (1) |
$ |
13.02 |
$ |
18.61 |
(30) | |||
Transportation |
1.63 |
1.35 |
21 | |||||
Financing |
5.70 |
4.31 |
33 | |||||
Share-based compensation |
$ |
0.38 |
$ |
0.01 |
100 |
(1) |
Includes the effect of carried operating expenses from its partner under the Peace River Oil Partnership of $4 million or $0.52 per boe (2015 - $3 million or $0.36 per boe). |
Operating
In 2016, the Company successfully progressed on a number of strategies to reduce operating costs, with a specific focus on reducing repair & maintenance and workover activities. These efforts, combined with favorable weather conditions during the first quarter led to current and prior estimates coming in below the Company's initial expectations. The Company's production results for the first quarter of 2016, which were ahead of its expectations, also supported the reduced per boe figure. Penn West will continue to review its operations and seek further improvements in its cost structure as it moves forward. Due to the strong result in the first quarter of 2016 the Company is reducing its annual operating cost per boe target for 2016 to $17.00 - $18.00 per boe, from $18.00 - $18.75 per boe, despite several required maintenance and turnaround activities in the second half of 2016.
Operating costs were also lower from the comparative periods as a result of the Company's asset disposition program which has removed several non-core, high operating cost properties from its portfolio and a decline in labour costs due to reduced staff levels over the past year.
Operating expenses for the first three months of 2016 included a realized loss of $2 million (2015 – $5 million loss) on electricity contracts.
Financing
At March 31, 2016, the Company had a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion and an extendible five-year term (May 6, 2019 maturity date). The syndicated bank facility contains provisions for stamping fees on bankers' acceptances and LIBOR loans and standby fees on unutilized credit lines that vary depending on certain financial ratios. At March 31, 2016, the Company had $686 million of unused credit capacity available.
At March 31, 2016, the value of the Company's senior notes was $1.4 billion (December 31, 2015 – $1.5 billion). There were no senior notes issued in either 2016 or 2015.
Summary information on our senior notes outstanding is as follows at March 31, 2016:
Issue date |
Amount (millions) |
Term |
Average interest |
Weighted average remaining | ||||||
2007 Notes |
May 31, 2007 |
US$194 |
8 – 15 years |
7.86% |
2.3 | |||||
2008 Notes |
May 29, 2008 |
US$334, CAD$30 |
8 – 12 years |
8.24% |
1.7 | |||||
UK Notes |
July 31, 2008 |
£34 |
10 years |
6.95% (2) |
2.3 | |||||
2009 Notes |
May 5, 2009 |
US$64(3), £14, €6 |
5 – 10 years |
10.53% (4) |
2.2 | |||||
2010 Q1 Notes |
March 16, 2010 |
US$148 |
5 – 15 years |
7.68% |
3.4 | |||||
2010 Q4 Notes |
December 2, 2010, |
US$121, CAD$27 |
5 – 15 years |
6.94% |
5.4 | |||||
2011 Notes |
November 30, 2011 |
US$76, CAD$16 |
5 – 10 years |
6.49% |
4.0 |
(1) |
Average interest rate can fluctuate based on debt to EBITDA ratio which expires on March 30, 2017, the date the covenant relief period ends with the bank syndicate and noteholders. |
(2) |
These notes currently bear interest at 8.95 percent in Pounds Sterling, however, contracts were entered to fix the interest rate at 6.95 percent in Canadian dollars and to fix the exchange rate on the repayment. |
(3) |
A portion of the 2009 Notes have equal repayments, which began in 2013 with a repayment of US$5 million, and extend over the remaining six years. |
(4) |
The Company entered into contracts to fix the interest rate on the Pounds Sterling and Euro tranches, at 11.15 percent and 11.22 percent, to 9.15 percent and 9.22 percent, respectively, and to fix the exchange rate on repayment. |
Penn West's debt structure includes short-term financings under its syndicated bank facility and long-term financing through its senior notes. Financing charges in 2016 increased compared to 2015 as there was a higher balance drawn under the Company's syndicated bank facility. Additionally, in May 2015, the Company finalized amended agreements with the lenders under its syndicated bank facility and with the holders of its senior notes which resulted in amended financial covenants and led to increases in the fee structure. The fee structure on the Company's senior notes will change during the amendment period (up until March 30, 2017) as follows:
Senior debt to EBITDA ratio |
Basis points per | |||
Less than or equal to 3:1 |
50 | |||
Greater than 3:1 and less than or equal to 4:1 |
100 | |||
Greater than 4:1 and less than or equal to 4.5:1 |
150 | |||
Greater than 4.5:1 |
200 |
See "Liquidity and Capital Resources – Liquidity" for further details on the amendments.
The interest rates on any non-hedged portion of the Company's syndicated bank facility are subject to fluctuations in short-term money market rates as advances on the syndicated bank facility are generally made under short-term instruments. As at March 31, 2016, 25 percent (December 31, 2015 – 24 percent) of Penn West's long-term debt instruments were exposed to changes in short-term interest rates.
Share-Based Compensation
Share-based compensation expense relates to the Company's Stock Option Plan (the "Option Plan"), Restricted Share Unit Plan ("RSU"), Deferred Share Unit Plan ("DSU") and Performance Share Unit Plan ("PSU").
Share-based compensation consisted of the following:
Three months ended March 31 | ||||||||
(millions) |
2016 |
2015 |
% change | |||||
Options |
$ |
1 |
$ |
1 |
- | |||
RSU – liability method |
1 |
(1) |
>100 | |||||
RSU – equity method |
1 |
- |
100 | |||||
Share-based compensation |
$ |
3 |
$ |
- |
100 |
The share price used in the fair value calculation of the RSU plan under the liability method, PSU and DSU obligations at March 31, 2016 was $1.20 (March 31, 2015 – $2.09). Share-based compensation related to the DSU and PSU was insignificant in both periods.
General and Administrative Expenses
Three months ended March 31 | |||||||||
(millions, except per boe amounts) |
2016 |
2015 |
% change | ||||||
Gross |
$ |
20 |
$ |
38 |
(47) | ||||
Per boe |
2.88 |
4.42 |
(35) | ||||||
Net |
14 |
22 |
(36) | ||||||
Per boe |
$ |
1.97 |
$ |
2.55 |
(23) |
During 2015 and in early 2016, the Company continued to focus its operations and aligned its organizational structure to current activity levels which resulted in a reduction in its workforce and a lower cost structure. In 2016, Penn West also released its 2015 bonus provision totaling $2 million which contributed to the decrease. The Company is continuing to forecast 2016 G&A per boe figure at $2.50 - $2.90.
Restructuring Expense
Three months ended March 31 | |||||||||
(millions, except per boe amounts) |
2016 |
2015 |
% change | ||||||
Restructuring |
$ |
6 |
$ |
2 |
>100 | ||||
Per boe |
$ |
0.82 |
$ |
0.21 |
>100 |
During the first quarter of 2016, Penn West decreased its workforce in light of lower current activity levels and the weak commodity price environment resulting in increased restructuring expenses.
Depletion, Depreciation, Impairment and Accretion
Three months ended March 31 | |||||||
(millions, except per boe amounts) |
2016 |
2015 |
% change | ||||
Depletion and depreciation ("D&D") |
$ |
132 |
$ |
181 |
(27) | ||
D&D expense per boe |
18.78 |
21.21 |
(11) | ||||
Impairment |
132 |
- |
100 | ||||
Impairment per boe |
18.75 |
- |
100 | ||||
Accretion of decommissioning liability |
7 |
9 |
(22) | ||||
Accretion expense per boe |
$ |
1.06 |
$ |
1.10 |
(4) |
D&D expense decreased from the comparative period mainly due to impairment charges in 2015 and asset disposition activity as the Company progressed on several initiatives to strengthen its balance sheet and focus its operations.
During the first quarter of 2016, Penn West announced it had entered into a definitive sale agreement to sell certain assets located in the Slave Point area of Northern Alberta. As the sale was not closed by March 31, 2016, these assets were classified as held for sale and an impairment test was required. As the book value of these assets exceeded the fair value received a non-cash impairment charge of $96 million ($132 million before-tax) was recorded. Subsequent to quarter-end, on April 15, 2016, the transaction closed for proceeds of $148 million, subject to closing adjustments. The Company is committed to pursuing additional asset sales as it continues to focus on debt reduction.
Taxes
Three months ended March 31 | ||||||||||
(millions) |
2016 |
2015 |
% change | |||||||
Deferred tax recovery |
$ |
58 |
$ |
24 |
>100 |
The deferred income tax recovery recorded during the first quarter of 2016 was primarily the result of the non-cash impairment charges recorded on assets held for sale.
Foreign Exchange
Penn West records unrealized foreign exchange gains or losses to translate the U.S., UK and Euro denominated senior notes and the related accrued interest to Canadian dollars using the exchange rates in effect on the balance sheet date. Realized foreign exchange gains or losses are recorded upon repayment of the senior notes.
The split between realized and unrealized foreign exchange losses is as follows:
Three months ended March 31 | ||||||
2016 |
2015 |
% change | ||||
Realized foreign exchange loss on debt maturities |
$ |
- |
$ |
(6) |
(100) | |
Unrealized foreign exchange gain (loss) |
89 |
(168) |
>(100) | |||
Foreign exchange gain (loss) |
$ |
89 |
$ |
(174) |
>(100) |
The unrealized gain in 2016 is due to the strengthening of the Canadian dollar relative to the US dollar during the quarter.
Net Loss
Three months ended March 31 | ||||||||
(millions, except per share amounts) |
2016 |
2015 |
% change | |||||
Net loss |
$ |
(100) |
$ |
(248) |
(60) | |||
Basic per share |
(0.20) |
(0.49) |
(59) | |||||
Diluted per share |
$ |
(0.20) |
$ |
(0.49) |
(59) |
The net loss in the first quarter of 2016 was primarily due to a non-cash impairment charge as a result of classifying the Slave Point properties as assets held for sale. This was partially offset by unrealized foreign exchange gains due to the strengthening of the Canadian dollar compared to the US dollar.
Capital Expenditures
Three months ended March 31 | |||||
(millions) |
2016 |
2015 |
% change | ||
Drilling and completions |
$ |
16 |
$ |
129 |
(88) |
Facilities and well equipping |
16 |
60 |
(73) | ||
Geological and geophysical |
2 |
2 |
- | ||
Corporate |
- |
3 |
(100) | ||
Carried capital by partners |
(16) |
(3) |
>100 | ||
Development and exploration capital expenditures (1) |
18 |
191 |
(91) | ||
Property dispositions, net |
(33) |
(1) |
>100 | ||
Total capital expenditures |
$ |
(15) |
$ |
190 |
>(100) |
(1) |
Capital expenditures include costs related to Property, Plant and Equipment and Exploration and Evaluation activities. |
In 2016, the Company reduced its capital program as a result of the low commodity price environment as the Company is targeting its expenditures to be largely within funds flow from operations. Capital activities in the first quarter were focused on completion and tie-in activities within the Viking and development activity within the Peace River Oil Partnership where the Company has the full support of its joint venture partner and is carried on a portion of its capital expenditures.
The Company advanced its asset disposition program during the first quarter of 2016 closing minor property dispositions. Additionally, it entered into a transaction to sell assets located in the Slave Point area of Northern Alberta for proceeds of $148 million which closed in April 2016.
Exploration and evaluation ("E&E") capital expenditures
Three months ended March 31 | ||||||||||
(millions) |
2016 |
2015 |
% change | |||||||
E&E capital expenditures |
$ |
- |
$ |
7 |
(100) |
During 2016, E&E capital expenditures were insignificant as the Company reduced capital activity levels as a result of the low commodity price environment.
Gain on asset dispositions
Three months ended March 31 | ||||||||||||
(millions) |
2016 |
2015 |
% change | |||||||||
Gain on asset dispositions |
$ |
1 |
$ |
- |
100 |
In the first quarter of 2016, Penn West completed a number of minor non-core asset dispositions as it continued to reduce outstanding debt and focus its asset portfolio.
Environmental and Climate Change
The oil and gas industry has a number of environmental risks and hazards and is subject to regulation by all levels of government. Environmental legislation includes, but is not limited to, operational controls, site restoration requirements and restrictions on emissions of various substances produced in association with oil and natural gas operations. Compliance with such legislation could require additional expenditures and a failure to comply may result in fines and penalties which could, in the aggregate and under certain assumptions, become material.
Penn West is dedicated to reducing the environmental impact from its operations through its environmental programs which include resource conservation, water management and site abandonment/reclamation/remediation. Operations are continuously monitored to minimize environmental impact and allocate sufficient capital to reclamation and other activities to mitigate the impact on the areas in which the Company operates.
Liquidity and Capital Resources
Capitalization
March 31, 2016 |
December 31, 2015 | ||||||
(millions) |
% |
% | |||||
Common shares issued, at market (1) |
$ |
603 |
24 |
$ |
588 |
22 | |
Bank loans and long-term notes |
1,858 |
73 |
1,940 |
71 | |||
Working capital deficiency (2)(3) |
72 |
3 |
182 |
7 | |||
Total enterprise value |
$ |
2,533 |
100 |
$ |
2,710 |
100 |
(1) |
The share price at March 31, 2016 was $1.20 (December 31, 2015 - $1.17 per share). |
(2) |
Excludes the current portion of deferred funding asset, risk management, long-term debt and decommissioning liability. |
(3) |
The 2016 figure includes a $4 million working capital deficiency related to assets classified as held for sale. |
Dividends
Three months ended March 31 | |||||
(millions, except per share amounts) |
2016 |
2015 |
% change | ||
Dividends declared |
$ |
- |
$ |
5 |
(100) |
Per share |
- |
0.01 |
(100) | ||
Dividends paid (1) |
$ |
- |
$ |
70 |
(100) |
(1) |
Includes amounts funded by the dividend reinvestment plan. |
On September 1, 2015, Penn West announced that its Board of Directors approved the suspension of the dividend until further notice, following the October 15, 2015 payment.
The amount of future cash dividends may vary depending on a variety of factors and conditions which can include, but are not limited to, fluctuations in commodity markets, production levels and capital investment plans. Penn West's dividend level could change based on these and other factors and is subject to the approval of its Board of Directors. For further information regarding the Company's dividend policy, including the factors that could affect the amount of quarterly dividend that it pays, if any, and the risks relating thereto, see "Dividends and Dividend Policy – Dividend Policy" in its Annual Information Form, which is available on its website at www.pennwest.com, on the SEDAR website at www.sedar.com, and on the EDGAR website at www.sec.gov.
Liquidity
The Company has a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion and an extendible five-year term (May 6, 2019 maturity date). For further details on the Company's debt instruments, please refer to the "Financing" section of this MD&A.
The Company actively manages its debt portfolio and considers opportunities to reduce or diversify its debt capital structure. Management contemplates both operating and financial risks and takes action as appropriate to limit the Company's exposure to certain risks. Management maintains close relationships with the Company's lenders and agents to monitor credit market developments. These actions and plans aim to increase the likelihood of maintaining the Company's financial flexibility and capital program, supporting the Company's ability to capture opportunities in the market and execute longer-term business strategies.
If the current low commodity price environment continues, the Company anticipates it will not be in compliance with certain of its existing financial covenants by the end of the second quarter of 2016. The Company is engaged in negotiations with its lenders to amend these financial covenants prior to the end of the second quarter of 2016, which if successful will mitigate the risk of default in 2016 and further into the future at prevailing commodity price levels. In order to reduce this risk of default, the Company is continuing to pursue additional asset dispositions and is considering several other options which include obtaining additional sources of capital from strategic investors. As there is the potential that the Company will not be in compliance with its financial covenants at the end of the second quarter of 2016, there is a risk of default under the Company's bank facility and noteholder agreements. This has resulted in uncertainty on the Company's ability to continue as a going concern.
The Company has a number of covenants related to its syndicated bank facility and senior notes. On March 31, 2016, the Company was in compliance with all of these financial covenants which consisted of the following:
Limit |
March 31, 2016 | |||||||||||||
Senior debt to EBITDA (1) |
Less than 5:1 |
4.4 | ||||||||||||
Total debt to EBITDA (1) |
Less than 5:1 |
4.4 | ||||||||||||
Senior debt to capitalization |
Less than 50% |
40% | ||||||||||||
Total debt to capitalization |
Less than 55% |
40% |
(1) |
EBITDA is calculated in accordance with Penn West's lending agreements wherein unrealized risk management gains and losses and impairment provisions are excluded. |
The table below outlines the Company's senior debt to EBITDA calculation as at March 31, 2016:
Three months ended |
Trailing 12 months | |||||||||
Mar. 31 |
Dec. 31 |
Sep. 30 |
Jun 30 |
Mar. 31 | ||||||
(millions, except ratios) |
2016 |
2015 |
2015 |
2015 |
2016 | |||||
Funds Flow |
$ |
89 |
$ |
7 |
$ |
14 |
$ |
47 |
$ |
157 |
Financing |
40 |
42 |
40 |
43 |
165 | |||||
Realized gain on foreign exchange hedges on prepayments |
- |
(9) |
(6) |
(3) |
(18) | |||||
Realized foreign exchange loss – debt prepayments |
- |
64 |
15 |
44 |
123 | |||||
Restructuring expenses |
6 |
6 |
22 |
3 |
37 | |||||
EBITDA |
$ |
135 |
$ |
110 |
$ |
85 |
$ |
134 |
$ |
464 |
EBITDA contribution from assets sold (1) |
(35) | |||||||||
EBITDA as defined by debt agreements |
$ |
429 | ||||||||
Long-term debt |
$ |
1,858 | ||||||||
Letters of credit – financial (2) |
11 | |||||||||
Total senior debt |
$ |
1,869 | ||||||||
Senior debt to EBITDA |
4.4 |
(1) |
Consists of EBITDA contributions from assets that have been disposed in the prior 12 months. |
(2) |
Letters of credit that are classified as financial are included in the senior debt calculation per the debt agreements. |
In May 2015, the Company finalized amending agreements with the lenders under its syndicated bank facility and with the holders of its senior notes to, among other things, amend its financial covenants as follows:
The Company also agreed to the following:
Financial Instruments
The Company had the following financial instruments outstanding as at March 31, 2016. Fair values are determined using external counterparty information, which is compared to observable market data. Penn West limits its credit risk by executing counterparty risk procedures which include transacting only with institutions within its syndicated bank facility or with high credit ratings and by obtaining financial security in certain circumstances.
Notional |
Remaining term |
Pricing |
Fair value | |||
Natural gas |
||||||
AECO Swaps |
14,000 mcf/d |
Apr/16 – Dec/16 |
$3.05/mcf |
$ |
6 | |
AECO Swaps |
4,700 mcf/d |
Apr/16 – Dec/16 |
$2.69/mcf |
1 | ||
Crude Oil |
||||||
WTI Swaps |
2,000 bbl/d |
Apr/16 – Jun/16 |
$68.25/bbl |
3 | ||
WTI Swaps |
1,000 bbl/d |
Jul/16 – Sep/16 |
$66.05/bbl |
1 | ||
WTI Swaps |
1,000 bbl/d |
Oct/16 – Dec/16 |
$67.05/bbl |
1 | ||
WTI Swaps |
5,000 bbl/d |
Apr/16 – Dec/16 |
$72.08/bbl |
28 | ||
WTI Swaps |
3,000 bbl/d |
Jan/17 – Mar/17 |
$69.37/bbl |
3 | ||
Electricity swaps |
||||||
Alberta Power Pool |
25 MW |
Apr/16 – Dec/16 |
$49.90/MWh |
(3) | ||
Crude oil assignment |
||||||
18 – month term |
10,000 boe/d |
Apr/16 – May/16 |
Differential WCS (Edm) vs. WCS (USGC) |
1 | ||
Foreign exchange forwards on senior notes |
||||||
3 to 15-year initial term |
US$25 |
2017 |
1.000 CAD/USD |
7 | ||
Short-term (< 1 year) |
US$30 |
2016 |
1.402 CAD/USD |
(2) | ||
Cross currency swaps |
||||||
10-year initial term |
£57 |
2018 |
2.0075 CAD/GBP, 6.95% |
(7) | ||
10-year initial term |
£20 |
2019 |
1.8051 CAD/GBP, 9.15% |
2 | ||
10-year initial term |
€10 |
2019 |
1.5870 CAD/EUR, 9.22% |
(1) | ||
Total |
$ |
40 |
The components of risk management gain (loss) were as follows:
Three months ended March 31 | ||||||
2016 |
2015 |
% change | ||||
Realized |
||||||
Settlement of commodity contracts/assignment |
$ |
38 |
$ |
11 |
>100 | |
Monetization of commodity contracts |
2 |
18 |
(88) | |||
Settlement of foreign exchange contracts |
- |
2 |
(100) | |||
Monetization of foreign exchange contracts |
32 |
44 |
(27) | |||
Total realized risk management gain (loss) |
72 |
75 |
(4) | |||
Unrealized |
||||||
Commodity contracts |
(2) |
(25) |
(92) | |||
Electricity swaps |
1 |
(4) |
>(100) | |||
Crude oil assignment |
(1) |
(3) |
(67) | |||
Foreign exchange contracts |
(46) |
6 |
>(100) | |||
Cross-currency swaps |
(16) |
3 |
>(100) | |||
Total unrealized risk management loss |
(64) |
(23) |
>100 | |||
Risk management gain |
$ |
8 |
$ |
52 |
(85) |
In the first quarter of 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes and unwound AECO swap contracts totalling 14,100 mcf per day.
Outlook
Due to strong well performance and production results, the Company's annual production guidance between 60,000 – 64,000 boe per day remains unchanged after the effect of the property dispositions closed during the first quarter of 2016 and the Slave Point disposition that was closed in April 2016. Additionally, as a result of successful cost savings initiatives and production results in the first quarter of 2016, the Company is reducing its annual operating cost per boe target to $17.00 - $18.00 per boe, from $18.00 - $18.75 per boe. For 2016, the Company's exploration and development capital expenditures budget of $50 million and G&A per boe of $2.50 - $2.90 remain unchanged, as previously disclosed in its January 28, 2016 press release.
This outlook section is included to provide shareholders with information about Penn West's expectations as at May 13, 2016 for production, exploration and development capital expenditures, operating costs per boe and G&A per boe in 2016 and readers are cautioned that the information may not be appropriate for any other purpose. This information constitutes forward-looking information. Readers should note the assumptions, risks and discussion under "Forward-Looking Statements" and are cautioned that numerous factors could potentially impact Penn West's capital expenditure levels, production, operating cost and G&A expenditures performance for 2016, including fluctuations in commodity prices and its ongoing asset disposition program.
All press releases are available on Penn West's website at www.pennwest.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov.
Sensitivity Analysis
Estimated sensitivities to selected key assumptions on funds flow for the 12 months subsequent to the date of this MD&A, including risk management contracts entered to date, are based on forecasted results as discussed in the Outlook above.
Impact on funds flow | ||||||||
Change of: |
Change |
$ millions |
$/share | |||||
Price per barrel of liquids |
$1.00 |
12 |
0.02 | |||||
Liquids production |
1,000 bbls/day |
13 |
0.03 | |||||
Price per mcf of natural gas |
$0.10 |
4 |
0.01 | |||||
Natural gas production |
10 mmcf/day |
2 |
- | |||||
Effective interest rate |
1% |
7 |
0.01 | |||||
Exchange rate ($US per $CAD) |
$0.01 |
3 |
0.01 |
Contractual Obligations and Commitments
Penn West is committed to certain payments over the next five calendar years and thereafter as follows:
2016 |
2017 |
2018 |
2019 |
2020 |
Thereafter | |||||||
Long-term debt |
$ |
209 |
$ |
223 |
$ |
353 |
$ |
657 |
$ |
248 |
$ |
168 |
Transportation |
11 |
11 |
7 |
7 |
6 |
8 | ||||||
Power infrastructure |
18 |
8 |
8 |
8 |
8 |
7 | ||||||
Drilling rigs |
6 |
7 |
- |
- |
- |
- | ||||||
Interest obligations |
95 |
90 |
69 |
35 |
16 |
20 | ||||||
Office lease (1) |
49 |
62 |
62 |
63 |
63 |
280 | ||||||
Decommissioning liability (2) |
$ |
19 |
$ |
21 |
$ |
20 |
$ |
19 |
$ |
18 |
$ |
299 |
(1) |
The future office lease commitments above are to be reduced by contracted sublease recoveries totalling $326 million. |
(2) |
These amounts represent the inflated, discounted future reclamation and abandonment costs that are expected to be incurred over the life of the Company's properties. |
The Company's syndicated bank facility is due for renewal on May 6, 2019. In addition, the Company has an aggregate of $1.4 billion in senior notes maturing between 2016 and 2025. If the Company is unsuccessful in renewing or replacing the syndicated bank facility or obtaining alternate funding for some or all of the maturing amounts of the senior notes, it is possible that it could be required to obtain other facilities, including term bank loans.
The Company is involved in various litigation and claims in the normal course of business and records provisions for claims as required.
In February 2016, Penn West announced it had entered into agreements to settle all class action proceedings in Canada and United States against the Company related to damages alleged to have been incurred due to a decline in share price related to the restatement of certain of Penn West's historical financial statements and related MD&A in 2014. The settlement agreements provide for a payment of $53 million split evenly between Canadian and US investors that is fully funded by insurance coverage maintained by Penn West. As a result, the payment will not impact the Company's cash or financial position. The proposed settlements are subject to the satisfaction of the conditions stated in the settlement documents as well as the receipt of court approval in each of Alberta, Ontario and Quebec and in New York. There can be no assurance that these conditions will be satisfied or that the settlements will be approved by the courts. The receipt of such court approvals is dependent on a number of factors and therefore the timing thereof cannot be predicted at this time.
Equity Instruments
Common shares issued: |
|||||||
As at March 31, 2016 and May 13, 2016 |
502,162,988 | ||||||
Options outstanding: |
|||||||
As at March 31, 2016 |
12,518,694 | ||||||
Granted |
18,500 | ||||||
Forfeited |
(361,098) | ||||||
As at May 13, 2016 |
12,176,096 |
Changes in Internal Control Over Financial Reporting ("ICFR")
Penn West's senior management has evaluated whether there were any changes in the Company's ICFR that occurred during the period beginning on January 1, 2016 and ending on March 31, 2016 that have materially affected, or are reasonably likely to materially affect, the Company's ICFR. No changes to Penn West's ICFR were made during the quarter.
Penn West utilizes the original Internal Control - Integrated Framework (2013) issued by the Committee of the Sponsoring Organizations of the Treadway Commission (COSO) to design and evaluate its internal control over financial reporting.
Future Accounting Pronouncements
The IASB issued IFRS 15 "Revenue from Contracts with Customers" which replaces IAS 18 "Revenue". IAS 15 specifies revenue recognition criteria and expanded disclosures for revenue. The new standard is effective for annual periods beginning on or after January 1, 2018 and early adoption is permitted. Penn West is currently assessing the impact of the standard.
The IASB completed the final sections of IFRS 9 "Financial Instruments" which replaces IAS 39 "Financial Statement: Recognition and Measurement". IFRS 9 provides guidance on the recognition and measurement, impairment and derecognition on financial instruments. The new standard is effective for annual periods beginning on or after January 1, 2018 and early adoption is permitted. Penn West is currently assessing the impact of the standard.
The IASB issued IFRS 16 "Leases" in January 2016 which replaces IAS 17 "Leases". IFRS 16 outlines several new requirements in regards to the recognition, measurement and disclosure of leases. A key principle within the standard includes a single lessee accounting model which requires lessees to recognise assets and liabilities for all leases which have a term more than 12 months. The accounting for lessors, which classify leases as either operating or finance, remains substantially unchanged from the previous standard. The new standard is effective for annual reporting periods beginning on or after 1 January 2019. Penn West is currently assessing the impact of the standard.
Off-Balance-Sheet Financing
The Company has off-balance-sheet financing arrangements consisting of operating leases. The operating lease payments are summarized in the "Contractual Obligations and Commitments section" of this MD&A.
Non-GAAP Measures
Certain financial measures including funds flow, funds flow from operations, funds flow per share-basic, funds flow per share-diluted, funds flow from operations per share-basic, funds flow from operations per share-diluted, netback, EBITDA and gross revenues included in this MD&A do not have a standardized meaning prescribed by IFRS and therefore are considered non-GAAP measures; accordingly, they may not be comparable to similar measures provided by other issuers. Funds flow is cash flow from operating activities before changes in non-cash working capital and decommissioning expenditures. Funds flow from operations excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is more representative of cash related to continuing operations. Funds flow and Funds flow from operations are used to assess the Company's ability to fund dividend and planned capital programs. See "Calculation of Funds Flow and Funds Flow from Operations" above for a reconciliation of funds flow to its nearest measure prescribed by IFRS. Netback is the per unit of production amount of revenue less royalties, operating expenses, transportation and realized risk management gains and losses, and is used in capital allocation decisions and to economically rank projects. See "Results of Operations – Netbacks" above for a calculation of the Company's netbacks. EBITDA is Funds Flow excluding the impact of financing expenses, realized gains and losses on foreign exchange hedges on prepayments, realized foreign exchange gains and losses on debt prepayments and restructuring expenses. EBITDA as defined by Penn West's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Penn West's covenant calculations related to its syndicated bank facility and senior notes. Gross revenue is total revenues including realized risk management gains and losses on commodity contracts and is used to assess the cash realizations on commodity sales.
Oil and Gas Information
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: under "Business Strategy", the Company intends to continue to advance on its core strategies as it focuses on debt reduction and the long-term sustainability of the Company, targeting capital expenditure to be within funds flow from operations at current commodity prices, continuing to assess development plans and adjust activity accordingly, continuing to focus on cost reductions, assessing how to apply disposition proceed pre-payments during the second quarter of 2016, continuing to pursue additional asset sales as a means to further reduce debt and focus operations, continuing to work on several initiatives to further reduce debt levels, continuing to seek improvements in cost structure and debt levels to be well positioned to move forward once commodity prices recover; under "Results of Operations", maintaining average production guidance after taking into account certain dispositions; under "Expenses - Operating", continuing to review operations and cost structure as the Company moves forward through 2016 and maintaining previously disclosed operating costs per boe for 2016; under "General and Administrative Expenses", anticipated range for G&A per boe for 2016; under "Depletion, Depreciation, Impairment and Accretion", remaining committed to pursuing additional asset sales and to continue to focus on debt reduction; under "Capital Expenditures"; targeting expenditures to be largely within funds flow from operations; under "Environmental and Climate Change", our belief that compliance with environmental legislation could require additional expenditures and a failure to comply with such legislation may result in fines and penalties which could, in the aggregate and under certain assumptions, become material, our intent to reduce the environmental impact from our operations through environmental programs; under "Liquidity and Capital Resources", considering opportunities to reduce or diversify the debt capital structure, our belief that our actions increase the likelihood of maintaining our financial flexibility and capital programs, which supports the Company's ability to capture opportunities in the market and execute longer-term business strategies, the anticipation that if the current low commodity price environment continues the Company will not be in compliance with certain of its existing financial covenants by the end of the second quarter of 2016, if negotiations will the lenders are successful it will mitigate the risk of default in 2016 and further into the future at prevailing commodity price levels, reducing default risk by continuing to pursue additional asset dispositions and other considerations including obtaining additional sources of capital from strategic investors, the potential of not being in compliance with financial covenants at the end of the second quarter of 2016 and therefore risk of default under the Company's bank facility and noteholder agreements; under "Outlook", the annual production guidance range, capital expenditure budget, annual average operating costs range per boe and G&A per boe range for 2016; under "Sensitivity Analysis", the estimated sensitivities to selected key assumptions on funds flow for the 12 months subsequent to this MD&A; and under "Contractual Obligations and Commitments", the terms and conditions of our class action settlement and being subject to the satisfaction of conditions stated in the settlement documents as well as court approvals in certain jurisdictions. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future.
With respect to forward-looking statements contained in this document, the Company has made assumptions regarding, among other things: that the Company does not dispose of additional material producing properties or royalties or other interests therein; that the current commodity price and foreign exchange environment will continue or improve; future capital expenditure levels; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future crude oil, natural gas liquids and natural gas production levels; future exchange rates and interest rates; future debt levels; and the continued suspension of our dividend.
Although the Company believes that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the forward-looking statements contained herein will not be correct, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that the Company will not be able to continue to successfully execute our long-term plan in part or in full, and the possibility that some or all of the benefits that the Company anticipates will accrue to our Company and our security holders as a result of the successful execution of such plan do not materialize; the possibility that the Company is unable to execute some or all of our ongoing asset disposition program on favorable terms or at all; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior, unsecured notes; general economic and political conditions in Canada, the U.S. and globally, and in particular, the effect that those conditions have on commodity prices and our access to capital; industry conditions, including fluctuations in the price of crude oil, natural gas liquids and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed (including extreme cold during winter months, wild fires and flooding); and the other factors described under "Risk Factors" in our Annual Information Form and described in our public filings, available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, the Company does not undertake any obligation to publicly update any forward-looking statements. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
Additional Information
Additional information relating to Penn West, including Penn West's Annual Information Form, is available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
Penn West Petroleum Ltd. | ||||||||
(CAD millions, unaudited) |
Note |
March 31, 2016 |
December 31, 2015 | |||||
Assets |
||||||||
Current |
||||||||
Cash |
$ |
53 |
$ |
2 | ||||
Accounts receivable |
134 |
154 | ||||||
Other |
35 |
42 | ||||||
Deferred funding assets |
3 |
78 |
63 | |||||
Risk management |
9 |
44 |
44 | |||||
Assets held for sale |
4 |
182 |
- | |||||
526 |
305 | |||||||
Non-current |
||||||||
Deferred funding assets |
3 |
135 |
168 | |||||
Exploration and evaluation assets |
5 |
204 |
243 | |||||
Property, plant and equipment |
6 |
4,741 |
5,145 | |||||
Risk management |
9 |
8 |
63 | |||||
5,088 |
5,619 | |||||||
Total assets |
$ |
5,614 |
$ |
5,924 | ||||
Liabilities and Shareholders' Equity |
||||||||
Current |
||||||||
Accounts payable and accrued liabilities |
$ |
290 |
$ |
380 | ||||
Current portion of long-term debt |
7 |
275 |
222 | |||||
Decommissioning liability |
8 |
24 |
21 | |||||
Risk management |
9 |
5 |
3 | |||||
Liabilities related to assets held for sale |
4 |
38 |
- | |||||
632 |
626 | |||||||
Non-current |
||||||||
Long-term debt |
7 |
1,583 |
1,718 | |||||
Decommissioning liability |
8 |
345 |
376 | |||||
Risk management |
9 |
7 |
- | |||||
Deferred tax liability |
208 |
266 | ||||||
Other non-current liabilities |
2 |
3 | ||||||
2,777 |
2,989 | |||||||
Shareholders' equity |
||||||||
Shareholders' capital |
10 |
8,994 |
8,994 | |||||
Other reserves |
94 |
92 | ||||||
Deficit |
(6,251) |
(6,151) | ||||||
2,837 |
2,935 | |||||||
Total liabilities and shareholders' equity |
$ |
5,614 |
$ |
5,924 | ||||
See accompanying notes to the unaudited interim consolidated financial statements. |
Basis of presentation (Note 2a)
Subsequent event (Note 4)
Commitments and contingencies (Note 12)
Penn West Petroleum Ltd. | ||||||
Three months ended March 31 | ||||||
(CAD millions, except per share amounts, unaudited) |
Note |
2016 |
2015 | |||
Oil and natural gas sales and other income |
$ |
191 |
$ |
311 | ||
Royalties |
(7) |
(37) | ||||
184 |
274 | |||||
Risk management gain |
9 |
8 |
52 | |||
192 |
326 | |||||
Expenses |
||||||
Operating |
95 |
162 | ||||
Transportation |
11 |
11 | ||||
General and administrative |
14 |
22 | ||||
Restructuring |
6 |
2 | ||||
Share-based compensation |
11 |
3 |
- | |||
Depletion, depreciation and impairment |
6 |
264 |
181 | |||
Gain on dispositions |
6 |
(1) |
- | |||
Foreign exchange loss (gain) |
7 |
(89) |
174 | |||
Financing |
7 |
40 |
37 | |||
Accretion |
8 |
7 |
9 | |||
350 |
598 | |||||
Loss before taxes |
(158) |
(272) | ||||
Deferred tax recovery |
(58) |
(24) | ||||
Net and comprehensive loss |
$ |
(100) |
$ |
(248) | ||
Net loss per share |
||||||
Basic |
$ |
(0.20) |
$ |
(0.49) | ||
Diluted |
$ |
(0.20) |
$ |
(0.49) | ||
Weighted average shares outstanding (millions) |
||||||
Basic |
10 |
502.2 |
501.4 | |||
Diluted |
10 |
502.2 |
501.4 | |||
See accompanying notes to the unaudited interim consolidated financial statements. |
Penn West Petroleum Ltd. | ||||||
Three months ended March 31 | ||||||
(CAD millions, unaudited) |
Note |
2016 |
2015 | |||
Operating activities |
||||||
Net loss |
$ |
(100) |
$ |
(248) | ||
Depletion, depreciation and impairment |
6 |
264 |
181 | |||
Gain on dispositions |
6 |
(1) |
- | |||
Accretion |
8 |
7 |
9 | |||
Deferred tax recovery |
(58) |
(22) | ||||
Share-based compensation |
11 |
2 |
1 | |||
Unrealized risk management gain |
9 |
64 |
23 | |||
Unrealized foreign exchange loss (gain) |
7 |
(89) |
168 | |||
Decommissioning expenditures |
8 |
(2) |
(11) | |||
Change in non-cash working capital |
(26) |
55 | ||||
61 |
156 | |||||
Investing activities |
||||||
Capital expenditures |
(18) |
(191) | ||||
Property dispositions (acquisitions), net |
33 |
1 | ||||
Change in non-cash working capital |
(32) |
(78) | ||||
(17) |
(268) | |||||
Financing activities |
||||||
Increase in long-term debt |
7 |
7 |
189 | |||
Repayments of senior notes |
7 |
- |
(85) | |||
Realized foreign exchange loss on repayments |
7 |
- |
6 | |||
Dividends paid |
- |
(60) | ||||
7 |
50 | |||||
Change in cash |
51 |
(62) | ||||
Cash, beginning of period |
2 |
67 | ||||
Cash, end of period |
$ |
53 |
$ |
5 | ||
See accompanying notes to the unaudited interim consolidated financial statements. |
Penn West Petroleum Ltd. | |||||||||
(CAD millions, unaudited) |
|||||||||
Note |
Shareholders' |
Other Reserves |
Deficit |
Total | |||||
Balance at January 1, 2016 |
$ |
8,994 |
$ |
92 |
$ |
(6,151) |
$ |
2,935 | |
Net and comprehensive loss |
- |
- |
(100) |
(100) | |||||
Share-based compensation |
11 |
- |
2 |
- |
2 | ||||
Balance at March 31, 2016 |
$ |
8,994 |
$ |
94 |
$ |
(6,251) |
$ |
2,837 | |
(CAD millions, unaudited) |
Note |
Shareholders' |
Other Reserves |
Deficit |
Total | ||||
Balance at January 1, 2015 |
$ |
8,983 |
$ |
89 |
$ |
(3,490) |
$ |
5,582 | |
Net and comprehensive loss |
- |
- |
(248) |
(248) | |||||
Share-based compensation |
11 |
- |
1 |
- |
1 | ||||
Issued to dividend reinvestment plan |
10 |
10 |
- |
- |
10 | ||||
Dividends declared |
10 |
- |
- |
(5) |
(5) | ||||
Balance at March 31, 2015 |
$ |
8,993 |
$ |
90 |
$ |
(3,743) |
$ |
5,340 | |
See accompanying notes to the unaudited interim consolidated financial statements. |
Notes to the Unaudited Consolidated Financial Statements
(All tabular amounts are in CAD millions except numbers of common shares, per share amounts, percentages and various figures in Note 9)
1. Structure of Penn West
Penn West Petroleum Ltd. ("Penn West" or the "Company") is a senior exploration and production company and is governed by the laws of the Province of Alberta, Canada. The Company operates in one segment, to explore for, develop and hold interests in oil and natural gas properties and related production infrastructure in the Western Canada Sedimentary Basin directly and through investments in securities of subsidiaries holding such interests. Penn West's portfolio of assets is managed at an enterprise level, rather than by separate operating segments or business units. The Company assesses its financial performance at the enterprise level and resource allocation decisions are made on a project basis across Penn West's portfolio of assets, without regard to the geographic location of projects. Penn West owns the petroleum and natural gas assets or 100 percent of the equity, directly or indirectly, of the entities that carry on the remainder of the oil and natural gas business of Penn West, except for an unincorporated joint arrangement (the "Peace River Oil Partnership") in which Penn West's wholly owned subsidiaries hold a 55 percent interest.
Penn West operates under the trade names of Penn West and Penn West Exploration.
2. Basis of presentation and statement of compliance
a) Basis of Presentation
The interim consolidated financial statements include the accounts of Penn West, its wholly owned subsidiaries and its proportionate interest in partnerships. Results from acquired properties are included in Penn West's reported results subsequent to the closing date and results from properties sold are included until the closing date.
All intercompany balances, transactions, income and expenses are eliminated on consolidation.
Certain comparative figures have been reclassified to correspond with current period presentation.
The accompanying interim consolidated financial statements have been prepared on a going concern basis, which asserts that the Company has the ability to realize its assets and discharge its liabilities and commitments in the normal course of business as they become due.
If the current low commodity price environment continues, the Company anticipates it will not be in compliance with certain of its existing financial covenants by the end of the second quarter of 2016, specifically the Senior Debt/Total Debt to EBITDA covenant. The Company is engaged in negotiations with its lenders to amend these financial covenants prior to the end of the second quarter of 2016, which if successful will mitigate the risk of default in 2016 and further into the future at prevailing commodity price levels. In order to reduce this risk of default, the Company is continuing to pursue additional property dispositions and is considering several other options which include obtaining additional sources of capital from strategic investors.
As it is uncertain that the Company will be in compliance with its existing financial covenants at the end of the second quarter of 2016 or that the Company will be successful in amending the agreements with its lenders by the end of the second quarter of 2016 or in pursuing other options, there is a material uncertainty that casts substantial doubt in the Company's ability to continue as a going concern. These financial statements do not include adjustments in the carrying values of the assets and liabilities that would be necessary if the going concern assumption were not appropriate. Such adjustments could be material.
b) Statement of Compliance
These unaudited condensed interim consolidated financial statements ("interim consolidated financial statements") are prepared in compliance with IAS 34 "Interim Financial Reporting" and accordingly do not contain all of the disclosures included in Penn West's annual audited consolidated financial statements.
The interim consolidated financial statements were prepared using the same accounting policies, critical accounting judgments and key estimates as in the annual consolidated financial statements as at and for the year ended December 31, 2015.
All tabular amounts are in millions of Canadian dollars, except numbers of common shares, per share amounts, percentages and other figures as noted.
The interim consolidated financial statements were approved for issuance by the Board of Directors on May 13, 2016.
3. Deferred funding assets
Deferred funding amounts relate to Penn West's share of capital and operating expenses to be funded by Penn West's partner in the Peace River Oil Partnership and Penn West's share of capital expenditures to be funded by Penn West's partner in the Cordova Joint Venture. Amounts expected to be settled within the next 12 months are classified as current.
March 31, 2016 |
December 31, 2015 | |||||||||
Peace River Oil Partnership |
$ |
131 |
$ |
149 | ||||||
Cordova Joint Venture |
82 |
82 | ||||||||
Total |
$ |
213 |
$ |
231 | ||||||
Current portion |
$ |
78 |
$ |
63 | ||||||
Long-term portion |
135 |
168 | ||||||||
Total |
$ |
213 |
$ |
231 |
4. Assets and liabilities held for sale
Assets and liabilities classified as held for sale consisted of the following:
March 31, 2016 |
December 31, 2015 | |||
Assets held for sale |
||||
Working capital |
$ |
7 |
$ |
- |
Property, plant and equipment |
175 |
- | ||
$ |
182 |
$ |
- | |
Liabilities related to assets held for sale |
||||
Working capital |
$ |
11 |
$ |
- |
Decommissioning liability |
27 |
- | ||
$ |
38 |
$ |
- |
As a result of entering into a definitive sales agreement during the first quarter of 2016, at March 31, 2016, the Company classified certain assets located in the Slave Point area of Northern Alberta as assets held for sale. Subsequent to quarter-end, on April 15, 2016, the Slave Point disposition closed for total proceeds of $148 million, subject to closing adjustments.
On March 31, 2016, these assets were recorded at the lesser of fair value less costs to sell and their carrying amount, resulting in an impairment loss of $96 million ($132 million before-tax), of which $69 million ($94 million before-tax) related to PP&E properties and $27 million ($38 million before-tax) was related to E&E properties. The impairment expense has been recorded as additional depletion, depreciation and impairment on the Consolidated Statements of Loss.
5. Exploration and evaluation ("E&E") assets
Three months ended |
Year ended December 31, 2015 | |||
Balance, beginning of period |
$ |
243 |
$ |
505 |
Capital expenditures |
- |
10 | ||
Expense |
- |
(7) | ||
Impairment |
(38) |
(252) | ||
Transfers to PP&E |
(1) |
(13) | ||
Balance, end of period |
$ |
204 |
$ |
243 |
As outlined in Note 4, the Company recorded $27 million of E&E impairment ($38 million before-tax) as a result of classifying certain assets as assets held for sale. These calculations were based on the proceeds from the signed sales agreements that were entered into in late March 2016.
6. Property, plant and equipment ("PP&E")
Cost |
Three months ended |
Year ended December 31, 2015 | ||
Balance, beginning of period |
$ |
16,210 |
$ |
17,456 |
Capital expenditures |
18 |
460 | ||
Joint venture, carried capital |
16 |
31 | ||
Acquisitions |
- |
7 | ||
Dispositions |
(60) |
(1,539) | ||
Transfers from E&E |
1 |
13 | ||
Transfers to assets held for sale |
(419) |
- | ||
SR&ED tax credits |
- |
(29) | ||
Net decommissioning dispositions |
(6) |
(189) | ||
Balance, end of period |
$ |
15,760 |
$ |
16,210 |
Accumulated depletion and depreciation |
Three months ended |
Year ended December 31, 2015 | ||
Balance, beginning of period |
$ |
11,065 |
$ |
9,550 |
Depletion and depreciation |
132 |
667 | ||
Impairments |
94 |
1,700 | ||
Transfers to assets held for sale |
(244) |
- | ||
Dispositions |
(28) |
(852) | ||
Balance, end of period |
$ |
11,019 |
$ |
11,065 |
Net book value |
March 31, 2016 |
December 31, 2015 | ||
Total |
$ |
4,741 |
$ |
5,145 |
In 2016, Penn West recorded gains on dispositions of $1 million (2015 - nil).
As outlined in Note 4, the Company recorded $69 million of PP&E impairment ($94 million before-tax) as a result of classifying certain assets as assets held for sale. These calculations were based on the proceeds from the signed sales agreements that were entered into in late March 2016.
Impairments have been recorded as additional depletion, depreciation and impairment on the Consolidated Statements of Loss.
7. Long-term debt
Amount (millions) |
Maturity dates |
Average interest |
March 31, 2016 |
December 31, 2015 | |||
2007 Notes |
US$194 |
2016 – 2022 |
7.86% |
$ |
251 |
$ |
268 |
2008 Notes |
US$334, CAD$30 |
2016 – 2020 |
8.24% |
464 |
492 | ||
UK Notes |
£34 |
2018 |
6.95% (2) |
64 |
71 | ||
2009 Notes |
US$64(3), £14, €6 |
2016 – 2019 |
10.53%(4) |
119 |
126 | ||
2010 Q1 Notes |
US$148 |
2016 – 2025 |
7.68% |
192 |
205 | ||
2010 Q4 Notes |
US$121, CAD$27 |
2016 – 2025 |
6.94% |
185 |
195 | ||
2011 Notes |
US$76, CAD$16 |
2016 – 2021 |
6.49% |
114 |
121 | ||
Total senior secured notes |
1,389 |
1,478 | |||||
Syndicated bank facility advances |
469 |
462 | |||||
Total long-term debt |
$ |
1,858 |
$ |
1,940 |
(1) |
Average interest rate can fluctuate based on debt to EBITDA ratio which expires on March 30, 2017, the date the covenant relief period ends with the bank syndicate and noteholders. |
(2) |
These notes currently bear interest at 8.95 percent in Pounds Sterling, however, contracts were entered to fix the interest rate at 6.95 percent in Canadian dollars and to fix the exchange rate on the repayment (refer to Note 9). |
(3) |
A portion of the 2009 Notes have equal repayments, which began in 2013 with a repayment of US$5 million, and extend over the remaining six years. |
(4) |
The Company entered into contracts to fix the interest rate on the Pounds Sterling and Euro tranches, at 11.15 percent and 11.22 percent, to 9.15 percent and 9.22 percent, respectively, and to fix the exchange rate on repayment (refer to Note 9). |
There were no senior notes issued in either 2016 or 2015.
The split between current and non-current long-term debt is as follows:
March 31, 2016 |
December 31, 2015 | |||
Current portion |
$ |
275 |
$ |
222 |
Long-term portion |
1,583 |
1,718 | ||
Total |
$ |
1,858 |
$ |
1,940 |
Additional information on Penn West's senior notes is as follows:
March 31, 2016 |
December 31, 2015 | |||
Weighted average remaining life (years) |
2.8 |
3.1 | ||
Weighted average interest rate (1) |
7.9% |
7.6% |
(1) |
Includes the effect of cross currency swaps (refer to Note 9). |
At March 31, 2016, the Company had a secured, revolving syndicated bank facility with an aggregate borrowing limit of $1.2 billion maturing on May 6, 2019. The syndicated bank facility contains provisions for stamping fees on bankers' acceptances and LIBOR loans and standby fees on unutilized credit lines that vary depending on certain financial ratios. At March 31, 2016, the Company had $686 million of unused credit capacity available.
Drawings on the Company's bank facility are subject to fluctuations in short-term money market rates as they are generally held as short-term borrowings. At March 31, 2016, 25 percent (December 31, 2015 – 24 percent) of Penn West's long-term debt instruments were exposed to changes in short-term interest rates.
Letters of credit totalling $45 million were outstanding on March 31, 2016 (December 31, 2015 – $49 million) that reduce the amount otherwise available to be drawn on the syndicated bank facility.
Penn West records unrealized foreign exchange gains or losses on its senior notes as amounts are translated into Canadian dollars at the rate of exchange in effect at the balance sheet. The split between realized and unrealized foreign exchange is as follows:
Three months ended March 31 | ||||
2016 |
2015 | |||
Realized foreign exchange loss on debt maturities |
$ |
- |
$ |
(6) |
Unrealized foreign exchange gain (loss) |
89 |
(168) | ||
Foreign exchange gain (loss) |
$ |
89 |
$ |
(174) |
The Company is subject to certain financial covenants under its syndicated bank facility and senior notes. These types of financial covenants are typical for senior lending arrangements and include senior debt and total debt to EBITDA and Senior Debt and Total Debt to Capitalization, as more specifically defined in the applicable lending agreements. At March 31, 2016, the Company was in compliance with all of its financial covenants under such lending agreements.
In May 2015, the Company finalized amending agreements with the lenders under its syndicated bank facility and with the holders of its senior notes to, among other things, amend its financial covenants as follows:
The Company also agreed to the following:
As a result of the continued low commodity price environment, if current strip pricing continues, the Company anticipates it will not be in compliance with certain of its existing financial covenants by the end of the second quarter of 2016. The Company is engaged in negotiations with its lenders to amend these financial covenants prior to the end of the second quarter of 2016, which if successful will mitigate the risk of default in 2016 and further into the future at prevailing commodity price levels. In order to reduce this risk of default, the Company is continuing to pursue additional property dispositions and is considering several other options which include obtaining additional sources of capital from strategic investors.
8. Decommissioning liability
The decommissioning liability was determined by applying an inflation factor of 2.0 percent (December 31, 2015 – 2.0 percent) and the inflated amount was discounted using a credit-adjusted rate of 7.5 percent (December 31, 2015 – 7.5 percent) over the expected useful life of the underlying assets, currently extending over 50 years into the future.
The split between current and non-current decommissioning liability is as follows:
March 31, 2016 |
December 31, 2015 | |||
Current portion |
$ |
24 |
$ |
21 |
Long-term portion |
345 |
376 | ||
Total |
$ |
369 |
$ |
397 |
Changes to the decommissioning liability were as follows:
Three months ended March 31, 2016 |
Year ended | ||||
Balance, beginning of period |
$ |
397 |
$ |
585 | |
Net liabilities disposed (1) |
(1) |
(61) | |||
Increase (decrease) in liability due to change in estimate |
(5) |
(128) | |||
Liabilities settled |
(2) |
(36) | |||
Transfers to liabilities for assets held for sale |
(27) |
- | |||
Accretion charges |
7 |
37 | |||
Balance, end of period |
$ |
369 |
$ |
397 |
(1) |
Includes additions from drilling activity, facility capital spending and disposals related to net property dispositions. |
9. Risk management
Financial instruments consist of accounts receivable, fair values of derivative financial instruments, accounts payable and accrued liabilities, dividends payable and long-term debt. Except for the senior notes described in Note 7, the fair values of these financial instruments approximate their carrying amounts due to the short-term maturity of the instruments, the mark to market values recorded for the financial instruments and the market rate of interest applicable to the syndicated bank facility. At March 31, 2016, the estimated fair values of the principal and interest obligations of the outstanding notes totalled $1.3 billion (December 31, 2015 – $1.4 billion) compared to the carrying value of $1.4 billion (December 31, 2015 – $1.5 billion).
The fair values of all outstanding financial, commodity, power, interest rate and foreign exchange contracts are reflected on the balance sheet with the changes during the period recorded in income as unrealized gains or losses.
As at March 31, 2016 and December 31, 2015, the only asset or liability measured at fair value on a recurring basis was the risk management asset and liability, which was valued based on "Level 2 inputs" being quoted prices in markets that are not active or based on prices that are observable for the asset or liability.
The following table reconciles the changes in the fair value of financial instruments outstanding:
Risk management asset |
Three months ended |
Year ended December 31, 2015 | ||||
Balance, beginning of period |
$ |
104 |
$ |
114 | ||
Unrealized gain (loss) on financial instruments: |
||||||
Commodity collars, swaps and assignments |
(3) |
13 | ||||
Electricity swaps |
1 |
6 | ||||
Foreign exchange forwards |
(46) |
(47) | ||||
Cross currency swaps |
(16) |
18 | ||||
Total fair value, end of period |
$ |
40 |
$ |
104 |
Penn West had the following financial instruments outstanding as at March 31, 2016. Fair values are determined using external counterparty information, which is compared to observable market data. Penn West limits its credit risk by executing counterparty risk procedures which include transacting only with institutions within Penn West's syndicated bank facility or companies with high credit ratings and by obtaining financial security in certain circumstances.
Notional |
Remaining Term |
Pricing |
Fair value | |||
Natural gas |
||||||
AECO Swaps |
14,000 mcf/d |
Apr/16 – Dec/16 |
$3.05/mcf |
$ |
6 | |
AECO Swaps |
4,700 mcf/d |
Apr/16 – Dec/16 |
$2.69/mcf |
1 | ||
Crude Oil |
||||||
WTI Swaps |
2,000 bbl/d |
Apr/16 – Jun/16 |
$68.25/bbl |
3 | ||
WTI Swaps |
1,000 bbl/d |
Jul/16 – Sep/16 |
$66.05/bbl |
1 | ||
WTI Swaps |
1,000 bbl/d |
Oct/16 – Dec/16 |
$67.05/bbl |
1 | ||
WTI Swaps |
5,000 bbl/d |
Apr/16 – Dec/16 |
$72.08/bbl |
28 | ||
WTI Swaps |
3,000 bbl/d |
Jan/17 – Mar/17 |
$69.37/bbl |
3 | ||
Electricity swaps |
||||||
Alberta Power Pool |
25 MW |
Apr/16 – Dec/16 |
$49.90/MWh |
(3) | ||
Crude oil assignment |
||||||
18 – month term |
10,000 boe/d |
Apr/16 – May/16 |
Differential WCS (Edm) vs. WCS (USGC) |
1 | ||
Foreign exchange forwards on senior notes |
||||||
3 to 15-year initial term |
US$25 |
2017 |
1.000 CAD/USD |
7 | ||
Short-term (< 1 year) |
US$30 |
2016 |
1.402 CAD/USD |
(2) | ||
Cross currency swaps |
||||||
10-year initial term |
£57 |
2018 |
2.0075 CAD/GBP, 6.95% |
(7) | ||
10-year initial term |
£20 |
2019 |
1.8051 CAD/GBP, 9.15% |
2 | ||
10-year initial term |
€10 |
2019 |
1.5870 CAD/EUR, 9.22% |
(1) | ||
Total |
$ |
40 |
Based on March 31, 2016 pricing, a $1.00 change in the price per barrel of liquids would have changed pre-tax unrealized risk management by $3 million and a $0.10 change in the price per mcf of natural gas would change pre-tax unrealized risk management by $1 million.
The components of risk management on the Statement of Income (Loss) are as follows:
Three months ended March 31 | |||||
2016 |
2015 | ||||
Realized |
|||||
Settlement of commodity contracts/assignment |
$ |
38 |
$ |
11 | |
Monetization of commodity contracts |
2 |
18 | |||
Settlement of foreign exchange contracts |
- |
2 | |||
Monetization of foreign exchange contracts |
32 |
44 | |||
Total realized risk management gain (loss) |
72 |
75 | |||
Unrealized |
|||||
Commodity contracts |
(2) |
(25) | |||
Electricity swaps |
1 |
(4) | |||
Crude oil assignment |
(1) |
(3) | |||
Foreign exchange contracts |
(46) |
6 | |||
Cross-currency swaps |
(16) |
3 | |||
Total unrealized risk management loss |
(64) |
(23) | |||
Risk management gain |
$ |
8 |
$ |
52 |
Operating costs for the three months ended March 31, 2016 include a realized loss of $2 million (2015 – $5 million loss) on electricity contracts.
Market risks
Penn West is exposed to normal market risks inherent in the oil and natural gas business, including, but not limited to, commodity price risk, foreign currency rate risk, credit risk, interest rate risk and liquidity risk. The Company seeks to mitigate these risks through various business processes and management controls and from time to time by using financial instruments.
There have been no significant changes to these risks from those discussed in Penn West's annual audited consolidated financial statements.
Foreign currency rate risk
In 2016, the Company monetized a total of US$115 million of foreign exchange forward contracts on senior notes. At March 31, 2016, the following foreign currency forward contracts were outstanding:
Nominal Amount |
Settlement date |
Exchange rate | ||||||||||
Buy US$30 |
2016 |
1.402 CAD/USD | ||||||||||
Buy US$25 |
2017 |
1.000 CAD/USD |
Liquidity risk
Refer to Note 7 for a discussion on liquidity risk.
10. Shareholders' equity
i) Issued
Shareholders' capital |
Common Shares |
Amount | |||
Balance, January 1, 2015 |
497,320,087 |
$ |
8,983 | ||
Issued on exercise of equity compensation plans (1) |
- |
1 | |||
Issued to dividend reinvestment plan |
4,843,076 |
10 | |||
Balance, December 31, 2015 |
502,163,163 |
8,994 | |||
Cancellation of dividend reinvestment plan (2) |
(175) |
- | |||
Balance, March 31, 2016 |
502,162,988 |
$ |
8,994 |
(1) |
Upon exercise of options, the net benefit is recorded as a reduction of other reserves and an increase to shareholders' capital. |
(2) |
In March 2016, the Company cancelled its dividend reinvestment plan. |
ii) Earnings per share - Basic and Diluted
The weighted average number of shares used to calculate per share amounts was as follows:
Three months ended March 31 | |||||||
Average shares outstanding (millions) |
2016 |
2015 | |||||
Basic and Diluted |
502.2 |
501.4 | |||||
For the first quarter of 2016, 12.5 million shares (March 31, 2015 – 18.3 million) that would be issued under the Option Plan were excluded in calculating the weighted average number of diluted shares outstanding as they were considered anti-dilutive.
11. Share-based compensation
Stock Option Plan
Penn West has an Option Plan that allows Penn West to issue options to acquire common shares to officers, employees and other service providers.
Under the terms of the plan, at March 31, 2016, the number of options reserved for issuance under the Option Plan shall not exceed 5.25 percent of the aggregate number of issued and outstanding common shares of Penn West. Subsequent to quarter-end, in May 2016, the Option Plan was amended by the Board of Directors so that the number of options reserved for issuance under the Option Plan shall not exceed 4.25 percent of the aggregate number of issued and outstanding common shares of Penn West. The grant price of options is equal to the volume-weighted average trading price of the common shares on the TSX for a five-trading-day period immediately preceding the date of grant. Options granted to date vest over a four-year period and expire five years after the date of grant.
Three months ended March 31, 2016 |
Year ended December 31, 2015 | |||||
Options |
Number of Options |
Weighted Exercise Price |
Number of Options |
Weighted Exercise Price | ||
Outstanding, beginning of period |
10,595,728 |
$ |
10.21 |
14,460,158 |
$ |
13.91 |
Granted |
3,515,950 |
1.20 |
5,122,600 |
1.85 | ||
Forfeited/ Expired |
(1,592,984) |
20.11 |
(8,987,030) |
11.39 | ||
Outstanding, end of period |
12,518,694 |
$ |
6.09 |
10,595,728 |
$ |
10.21 |
Exercisable, end of period |
4,575,632 |
$ |
11.49 |
3,907,426 |
$ |
17.21 |
A Black-Scholes option-pricing model was used to determine the fair value of options granted under the Option Plan with the following fair value per option and weighted average assumptions:
Three months ended March 31 | ||||
2016 |
2015 | |||
Average fair value of options granted (per share) |
$ |
0.54 |
$ |
0.65 |
Expected life of options (years) |
4.0 |
4.0 | ||
Expected volatility (average) |
61.0% |
39.7% | ||
Risk-free rate of return (average) |
0.6% |
0.7% | ||
Dividend yield |
nil |
1.9% |
Restricted Share Unit ("RSU") plan
Penn West has a RSU plan whereby Penn West employees receive consideration that fluctuates based on Penn West's share price on the TSX. Eligible employees receive a grant of a specific number of units (each of which notionally represents a common share) that vest over a three-year period. In March 2016, the Board approved that the consideration can now be paid in either cash or shares at their discretion on new grants. The Company believes that future consideration will be in the form of shares purchased on the open market at prevailing market prices. Consideration on all previous grants prior to March 2016 will be paid in cash.
If the service requirements are met, the cash consideration paid is based on the number of units vested and the five-day weighted average trading price of the common shares prior to the vesting date plus dividends declared by Penn West during the period preceding the vesting date. If the consideration is provided in shares, each outstanding RSU would be exchanged for one common share.
As consideration can now be in the form of cash or shares, all grants subsequent to March 2016 will be accounted for based on the equity method.
RSU plan (number of shares equivalent) |
Three months ended March 31, 2016 |
Year ended |
Outstanding, beginning of period |
6,325,954 |
3,166,476 |
Granted |
11,257,220 |
9,156,290 |
Vested |
(2,143,513) |
(1,281,077) |
Forfeited |
(641,563) |
(4,715,735) |
Outstanding, end of period |
14,798,098 |
6,325,954 |
Outstanding – liability method |
3,811,548 |
6,325,954 |
Outstanding – equity method |
10,986,550 |
- |
The fair value of the RSU plan units under the equity method used the following weighted average assumptions:
Three months ended March 31 | ||||
2016 |
2015 | |||
Average fair value of units granted (per unit) |
$ |
1.20 |
$ |
- |
Expected life of units (years) |
3.0 |
- | ||
Expected forfeiture rate |
19.0% |
- | ||
Dividend yield |
nil |
- |
At March 31, 2016, RSU plan obligations of $5 million were classified as a current liability (December 31, 2015 – $3 million) included in accounts payable and accrued liabilities and $1 million was classified as a non-current liability (December 31, 2015 – $2 million) included in other non-current liabilities.
Deferred Share Unit ("DSU") plan
The DSU plan allows Penn West to grant DSUs in lieu of cash fees to non-employee directors providing a right to receive, upon retirement, a cash payment based on the volume-weighted-average trading price of the common shares on the TSX for the five trading days immediately prior to the day of payment. Management directors are not eligible to participate in the DSU plan. At March 31, 2016, 569,143 DSUs (December 31, 2015 – 457,398) were outstanding and $1 million was recorded as a current liability (December 31, 2015 – $1 million).
Performance Share Unit ("PSU") plan
The PSU plan allows Penn West to grant PSUs to employees of Penn West. Upon meeting the vesting conditions, the employee could receive a cash payment based on performance factors determined by the Board of Directors and the share price. Members of the Board of Directors are not eligible for the PSU Plan.
PSU awards (number of shares equivalent) |
Three months ended March 31, 2016 |
Year ended |
Outstanding, beginning of period |
1,622,881 |
771,020 |
Granted |
2,316,000 |
1,483,000 |
Vested |
(129,881) |
(294,567) |
Forfeited |
- |
(336,572) |
Outstanding, end of period |
3,809,000 |
1,622,881 |
The PSU obligation is classified as a liability due to the cash settlement feature. The change in the fair value of outstanding PSU awards is charged to income based on the common share price at the end of each reporting period plus accumulated dividends multiplied by a performance factor determined by the Board of Directors. At March 31, 2016, $1 million was classified as a non-current liability (December 31, 2015 – $1 million) and included in other non-current liabilities.
Share-based compensation
Share-based compensation is based on the fair value of the options and units at the time of grant under the Option Plan and RSU plan (RSU's granted after March 2016), which is amortized over the remaining vesting period on a graded vesting schedule. Share-based compensation under the RSU plan on units granted prior to March 2016, DSU and PSU is based on the fair value of the awards outstanding at the reporting date and is amortized based on a graded vesting schedule. Share-based compensation consisted of the following:
Three months ended March 31 | ||||
2016 |
2015 | |||
Options |
$ |
1 |
$ |
1 |
RSU plan – liability method |
1 |
(1) | ||
RSU plan – equity method |
1 |
- | ||
Share-based compensation |
$ |
3 |
$ |
- |
The share price used in the fair value calculation of the RSU plan liability method, PSU and DSU obligations at March 31, 2016 was $1.20 (March 31, 2015 – $2.09). Share-based compensation related to the DSU and PSU was insignificant in both periods.
Employee retirement savings plan
Penn West has an employee retirement savings plan (the "savings plan") for the benefit of all employees. Under the savings plan, employees may elect to contribute up to 10 percent of their salary and Penn West matches these contributions at a rate of $1.50 for each $1.00 of employee contribution. Both the employee's and Penn West's contributions are used to acquire Penn West common shares or are placed in low-risk investments. Shares are purchased in the open market at prevailing market prices.
12. Commitments and contingencies
The Company is involved in various litigation and claims in the normal course of business and records provisions for claims as required.
In February 2016, Penn West announced it had entered into agreements to settle all class action proceedings in Canada and United States against the Company related to damages alleged to have been incurred due to a decline in share price related to the restatement of certain of Penn West's historical financial statements and related MD&A in 2014. The settlement agreements provide for a payment of $53 million split evenly between Canadian and US investors that is fully funded by insurance coverage maintained by Penn West. As a result, the payment will not impact the Company's cash or financial position. The proposed settlements are subject to the satisfaction of the conditions stated in the settlement documents as well as the receipt of court approval in each of Alberta, Ontario and Quebec and in New York. There can be no assurance that these conditions will be satisfied or that the settlements will be approved by the courts. The receipt of such court approvals is dependent on a number of factors and therefore the timing thereof cannot be predicted at this time.
SOURCE Penn West
CALGARY, May 3, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE.BC) ("Penn West", "we", "us" or "our") is expected to release its first quarter 2016 financial and operating results on Monday, May 16, 2016 before North American markets open. The first quarter 2016 management's discussion and analysis and unaudited consolidated financial statements will be available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov.
A presentation will accompany the conference call and will be available via the webcast. Alternatively, the presentation will be made available immediately prior to the conference call start time of 9:00 am Mountain Time on Penn West's website at: http://www.pennwest.com/investors/presentations-webcasts
CONFERENCE CALL & WEBCAST DETAILS
A conference call and webcast presentation will be held to discuss the matters noted above at 9:00 am Mountain Time (11:00 am Eastern Time) on Monday, May 16, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1185677&s=1&k=A0F472C7FAE5BBF7AD9D98F70F69BAD8
A digital recording will be available for replay two hours after the call's completion, and will remain available until May 30, 2016 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 5773377, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC"
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, Penn West expectation to release its first quarter 2016 financial and operating results on Monday, May 16, 2016 before North American markets open, that these statements will be available on the Company's website, SEDAR and EDGAR on the same date and that a conference call and webcast presentation discussing the results noted above will occur on Monday, May 16, 2016.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward-looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, April 18, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE.BC) ("Penn West", "we", "us" or "our") is pleased to announce that it has successfully closed the previously announced sale of its properties in the Slave Point area of Northern Alberta for cash consideration of approximately $148 million, subject to closing adjustments.
In addition, Penn West has closed approximately $50 million of its previously announced non-core asset sales of $80 million. It has also entered into a definitive agreement to sell the balance of such non-core assets for cash consideration of $30 million, subject to closing adjustments. The sale is expected to close in the second quarter.
About Penn West
Penn West is one of the largest conventional oil and natural gas producers in Canada. Our goal is to be the company that redefines oil & gas excellence in western Canada. Based in Calgary, Alberta, Penn West operates a significant portfolio of opportunities with a dominant position in light oil in Canada on a land base encompassing approximately 4 million acres.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, the expectation that the sale of non-core assets sales for cash consideration of approximately $30 million is expected to close by the end of the second quarter.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, March 21, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE.BC) ("Penn West", "we", "us" or "our") is pleased to announce that it has entered into a definitive agreement for the sale of its properties in the Slave Point area of Northern Alberta for cash consideration of $148 million, subject to closing adjustments customary in transactions of this nature.
Penn West is also pleased to announce that so far this year it has closed or entered into either definitive agreements or letters of intent to sell some of its non-core assets for aggregate cash consideration of approximately $80 million which, together with the proceeds from the sale of Slave Point, brings the total expected cash consideration from asset dispositions this year to approximately $230 million. These non-core asset sales are expected to close by the end of the second quarter. Penn West's asset disposition program has now raised over $1 billion in cash proceeds since the beginning of 2015.
"Although Slave Point has long been one of our core assets, given the current outlook for commodity prices, we had no development activity planned for at least the balance of this year. The proceeds from the sale of Slave Point and some of our non-core assets will help to strengthen our balance sheet and improve our financial flexibility and our overall corporate metrics," commented David Dyck, Senior Vice President and Chief Financial Officer of Penn West. "While we believe that Slave Point offers upside, the extension of our Viking play and recent Cardium performance provide us with ample development and growth opportunities and the most attractive rates of return in our portfolio. We are confident that our over 1,400 sections of land between those two plays will give us significant running room going forward."
The sale of Slave Point is expected to lower Penn West's corporate per barrel operating costs and reduce corporate decline rates. As a result of limited development capital allocated to Slave Point during 2015 and 2016, expected production declines for this area are approximately 35% and operating costs are estimated to increase to approximately $24.00 per boe over the remainder of the year.
The following are some of the key metrics and implied transaction multiples for the Slave Point properties based on our full year 2016 forecast:
Production (1) |
3,900 boe/d |
Liquids Weighting (1) |
97% |
Operating Cost (1) |
$20.00/boe |
Field Netback (1)(2) |
$15.00/boe |
Implied Production Multiple (1) |
$37,950/boe/d |
Implied Net Operating Income (NOI) Multiple (1)(2) |
7 times |
(1) |
Based on full year 2016 forecast |
(2) |
Assumes C$40/bbl Edmonton Par in Q1'16 and C$50/bbl Edmonton Par for the balance of 2016 |
The effective date of the sale of Slave Point is January 1, 2016 and closing is expected to occur during the second quarter of 2016, subject to the receipt of all necessary regulatory approvals and the satisfaction of closing conditions customary in transactions of this nature. RBC Capital Markets acted as our exclusive financial advisor on this disposition.
About Penn West
Penn West is one of the largest conventional oil and natural gas producers in Canada. Our goal is to be the company that redefines oil & gas excellence in western Canada. Based in Calgary, Alberta, Penn West operates a significant portfolio of opportunities with a dominant position in light oil in Canada on a land base encompassing approximately 4 million acres.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Forward-Looking Statements
Certain statements contained in this press release constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: that the non-core assets sales are expected to close by the end of the second quarter, that the sale of our Slave Point properties is expected to lower our corporate per barrel operating costs and reduce our corporate declines, that we expect production declines of approximately 35% and operating costs to increase to approximately $24.00 per boe over the remainder of the year , the key metrics and implied transaction multiples for the Slave Point properties based on our full year 2016 budget, and the effective date and the expected closing date of the sale of our Slave Point properties.
The key metrics for the Slave Point properties set forth in this press release may be considered to be future-oriented financial information or a financial outlook for the purposes of applicable Canadian securities laws. Financial outlook and future-oriented financial information contained in this press release are based on assumptions about future events based on management's assessment of the relevant information currently available. In particular, this press release contains projected operational information for 2016 for the Slave Point properties. The future-oriented financial information and financial outlooks contained in this press release have been approved by management as of the date of this press release. Readers are cautioned that any such financial outlook and future-oriented financial information contained herein should not be used for purposes other than those for which it is disclosed herein.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, March 10, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") announces that it has filed with Canadian securities regulatory authorities its audited Consolidated Financial Statements for the year ended December 31, 2015 and related Management's Discussion and Analysis. Penn West has also filed its Annual Information Form for the year ended December 31, 2015, which includes the disclosure and reports relating to reserves data and other oil and gas information required pursuant to National Instrument 51-101. Penn West's Annual Report on Form 40-F for the year ended December 31, 2015 will be filed with the U.S. Securities and Exchange Commission pursuant to its rules and regulations.
Copies of these documents may be obtained electronically via www.sedar.com and www.sec.gov/edgar.shtml (for the Form 40-F) or through Penn West's website at pennwest.com Hard copies of Penn West's audited Consolidated Financial Statements and related MD&A are also available upon request, free of charge, by contacting our Investor Relations group or by requesting them through our website.
Penn West shares are listed on the Toronto Stock Exchange under the symbol" PWT" and on the New York Stock Exchange under the symbol "PWE.BC"
SOURCE Penn West
CALGARY, Feb. 25, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") is expected to release its year ended 2015 financial and operating results as well as its 2015 reserves results on Thursday, March 10, 2016 before North American markets open. In addition, it is anticipated that the year ended 2015 management's discussion and analysis as well as the audited consolidated financial statements will be available on the Company's website at www.pennwest.com, on SEDAR at www.sedar.com, and on EDGAR at www.sec.gov on the same date.
CONFERENCE CALL & WEBCAST DETAILS
A conference call and webcast presentation will be held to discuss the matters noted above at 9:00 am Mountain Time (11:00 am Eastern Time) on Thursday, March 10, 2016.
To listen to the conference call, please call 647-427-7450 or 1-888-231-8191 (toll-free). This call will be broadcast live on the Internet and may be accessed directly at the following URL:
http://event.on24.com/r.htm?e=1134756&s=1&k=F31FDFEA49AE36DB64C651D092E7F1E6
A digital recording will be available for replay two hours after the call's completion, and will remain available until March 24, 2016 21:59 Mountain Time (23:59 Eastern Time). To listen to the replay, please dial 416-849-0833 or 1-855-859-2056 (toll-free) and enter Conference ID 49545110, followed by the pound (#) key.
Penn West shares are listed on the Toronto Stock Exchange under the symbol" PWT" and on the New York Stock Exchange under the symbol "PWE.BC"
FORWARD-LOOKING STATEMENTS
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, Penn West expectation to release its year ended 2015 financial, operating and reserve results on Thursday, March 10, 2016 before North American markets open, that these statements will be available on the company website, SEDAR and EDGAR on the same date and that a conference call and webcast presentation discussing the results noted above will occur on Thursday, March 10, 2016.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward-looking statements can be found in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, Feb. 16, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE - PWE) ("Penn West", "we", "us" or "our") announced today that it has entered into agreements to settle all class action proceedings in Canada and the United States against Penn West and others commenced by investors alleging damages in relation to Penn West's July 29, 2014 announcement that it intended to restate certain historical financial statements and related management discussion and analysis.
The settlement agreements provide for a payment that will be fully funded by insurance coverage maintained by Penn West. As a result, the payment will not impact Penn West's cash resources or financial position.
The settlement agreements contain no admission of liability or wrongdoing and include full releases of Penn West, current and former directors and officers of Penn West and others. Penn West is settling the class action proceedings in order to avoid the continuing risks, uncertainties and costs of litigation.
The proposed settlements are subject to the satisfaction of the conditions stated in the settlement documents as well as the receipt of court approval in each of Alberta, Ontario and Quebec and in New York. There can be no assurance that these conditions will be satisfied or that the settlements will be approved by the courts. The receipt of such court approvals is dependent on a number of factors and therefore the timing thereof cannot be predicted at this time.
About Penn West
Penn West is one of the largest conventional oil and natural gas producers in Canada. Our goal is to be the company that redefines oil & gas excellence in western Canada. Based in Calgary, Alberta, Penn West operates a significant portfolio of opportunities with a dominant position in light oil in Canada on a land base encompassing approximately 4 million acres.
Penn West shares are listed on the Toronto Stock Exchange under the symbol "PWT" and on the New York Stock Exchange under the symbol "PWE.BC".
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbor" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In particular, this document contains forward-looking statements pertaining to, without limitation, that the settlement will be fully funded by insurance coverage maintained by Penn West and will not affect Penn West's cash resources, that the proposed settlements are subject to the satisfaction of conditions stated in the settlement documents as well as the receipt of court approval in each of Alberta, Ontario and Quebec and in New York and that there can be no assurance that these conditions will be satisfied or that the settlements will be approved by the courts.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. Important factors that could cause actual results and events to differ from those described in the forward‑looking statements can be found in our public filings (including our Annual Information Form) available in Canada at http://www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
CALGARY, Jan. 28, 2016 /PRNewswire/ - PENN WEST PETROLEUM LTD. (TSX - PWT; NYSE – PWE.BC) ("Penn West", "we", "us" or "our") announces that the Board of Directors has approved a highly disciplined capital budget of $50 million for 2016. This budget responds to the significant decline in commodity prices and proposes capital spending levels 90 per cent lower than the 2015 planned capital program. Our 2016 capital budget is consistent with the strategy announced on September 1, 2015 which limits our total expenditures to funds flow from operations, while driving down our cost structure.
"Given the present state of the commodity price environment, our 2016 capital budget reflects the reality of living within our means at current price levels and managing the business on a week to week basis," stated Dave Roberts, President and CEO of Penn West. "In 2016, we will be prudent in limiting our capital expenditures to protect our balance sheet and we will continue our focus on the economics of every dollar we spend even at the expense of maintaining our production levels. We intend to only proceed on opportunities with near term payout at current price levels."
Dave Roberts added, "The progress we have made in driving down costs, protecting our balance sheet, reducing our capital expenditures and eliminating our dividend, as well as our asset dispositions of over $800 million dollars to reduce our leverage, clearly demonstrates how this company is delivering results for both our equity investors and our lenders."
2015 Operational Update
We had a strong finish to 2015 operations, with fourth quarter production volumes averaging over 77,000 boe/d. Full year production delivery was above the mid-point of guidance, despite capital expenditures that were approximately $20 million lower than our guidance of $500 million. Full year operating costs are expected to be below the bottom end of guidance and G&A is expected to be within the guidance range.
The 21 net wells we brought online in the fourth quarter in both the Crimson and Pembina areas of the Cardium continue to produce above our expectations. At the end of the year, we had one net well in the Cardium and 21 net wells in the Viking drilled but not yet brought on production. We plan to bring these wells on production in the first quarter of 2016. At the end of the year, we were operating only two drilling rigs at our PROP joint venture where a significant portion of our working interest capital and operating costs are carried by our partner.
Dave Roberts commented, "Looking forward, we believe that the long term value of our core business is reflected in our strong start to 2016, based on drilling results in the Cardium and Viking – I can say with confidence that, while we will continue to find ways to make our company more resilient to falling prices, when the commodity price recovers, our deep set of opportunities in our core plays will be there to create value for all Penn West stakeholders – and we will be ready to get back to work."
Production Outlook
Given our focus on managing the business at current price levels, we continue to monitor the profitability of each of our fields. Our Budget reflects expected shuts ins of up to 4,000 boe/d of uneconomic non-core production during the first quarter of 2016. We also anticipate that low commodity prices will weigh on the profitability of individual equipment repair or replacement projects at a certain portion of our non-core fields. Therefore, we estimate the deferral of these projects will reduce our 2016 annual average production by an additional 2,500 boe/d. We will be positioned to execute on these repair opportunities as the project economics improve to levels that warrant investment.
As a result of optimizing our operations for the current price environment, including the significant reductions to our capital program, we expect average annual production in 2016 between 60,000 boe/d and 64,000 boe/d, with a liquids weighting between 66% and 68%. These ranges do not take into account any potential dispositions. Our base decline remains approximately 20% to 22%.
Focus on Cost Structure
With a limited capital budget, the largest opportunity to reduce our cash outlays in 2016 will be through controlling our operating and G&A costs. We are aggressively identifying and implementing additional measures to reduce costs at our operated properties. Consequently, we expect to see an approximate 20% decrease in our absolute operating costs on a year over year, same field basis, which excludes the impact of dispositions. We expect these measures to save approximately $120 million of operating costs. For full year 2016, we expect operating costs to average between $18.00/boe and $18.75/boe.
We will continue to ensure that our organizational structure reflects our expectation of reduced activity levels in the foreseeable future. In addition to changes announced last September, we anticipate that we will be able to reduce our annual G&A costs by a further $15 to $20 million through initiatives already in progress. We expect 2016 average G&A costs will be in the $2.50/boe to $2.90/boe range.
2016 Capital Budget
Of our $50 million capital budget, we expect that approximately 30% of expenditures will be focused on our operated development programs. In particular, we will complete work on wells drilled at the end of 2015 in the Viking and Cardium, as well as to fund our portion of the primary development program at our PROP joint venture net of amounts carried by our partner. We do not anticipate starting work on any new wells in the Viking or the Cardium in the first half of the year.
Approximately 30% of our capital budget is allocated towards non-operated projects. However, we expect that if current price levels persist, our partners will seek to delay spending in some of these opportunities. We are in discussions with our partners to defer investment in some of these areas. To the extent these projects are delayed, it would create additional flexibility within our capital program.
A significant portion of the remaining capital will be for the replacement of critical infrastructure at core properties in the Cardium, where investment is required to maintain the reliability of our base production. In addition to our $50 million capital budget, we expect that our decommissioning expenditures for the year will be approximately $20 million.
We remain committed to limiting our combined capital budget and decommissioning expenditures to be within our funds flow from operations. We will remain prudent in our pace of spending to maintain optionality throughout the year in response to further volatility in commodity prices. We believe our non-core disposition program will help reduce capital requirements during the year and we continue to be in discussions with potential buyers across our non-core asset base. Proceeds from dispositions will be used to reduce our senior debt levels rather than to fund additional capital programs.
2016 Guidance and Sensitivity
Our guidance for 2016 is as follows:
Metric |
Guidance Range | ||
Annual Average Production |
boe/d |
60,000 – 64,000 | |
Liquids Weighting |
% |
66 – 68 | |
E&D Capital Expenditures |
$ millions |
$50 | |
Decommissioning Expenditures |
$ millions |
$20 | |
Operating Costs |
$/boe |
$18.00 – 18.75 | |
G&A Costs |
$/boe |
$2.50 – $2.90 |
This guidance does not reflect any potential disposition activity.
We continue to focus our operational strategy on current commodity price levels and are using current strip pricing in our calculations, which we believe to be very conservative. Despite this focus, we believe our enterprise continues to offer significant torque to a potential recovery in oil prices as outlined in the following table:
FY 2016 |
Jan 15, 2016 ~US$33 WTI |
US$40 WTI |
US$45 WTI | |
Funds Flow from Operations |
$ millions |
$0 - $40 |
$80 - $120 |
$140 - $180 |
EBITDA |
$ millions |
$155 - $195 |
$235 - $275 |
$295 - $335 |
All cases assume average 2016 AECO price of C$2.45/Mcf and average 2016 FX of C$1.45/US$.
About Penn West
Penn West is one of the largest conventional oil and natural gas producers in Canada. Our goal is to be the company that redefines oil & gas excellence in western Canada. Based in Calgary, Alberta, Penn West operates a significant portfolio of opportunities with a dominant position in light oil in Canada on a land base encompassing approximately 4 million acres.
Penn West shares are listed on the TSX under the symbol "PWT" and on the NYSE under the symbol "PWE.BC".
Oil and Gas Information Advisory
Barrels of oil equivalent ("boe") may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of crude oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency conversion ratio of 6:1, utilizing a conversion on a 6:1 basis is misleading as an indication of value.
Non-GAAP Measures
This news release includes non-GAAP measures not defined under International Financial Reporting Standards ("IFRS") including funds flow, funds flow from operations and EBITDA. Non-GAAP measures do not have any standardized meaning prescribed by GAAP and therefore may not be comparable to similar measures presented by other issuers. Funds flow is cash flow from operating activities before changes in non-cash working capital and decommissioning expenditures. Funds flow and funds flow from operations are used to assess the Penn West's ability to fund planned capital programs. Funds flow from operations excludes the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is more representative of cash related to continuing operations.
EBITDA is funds flow excluding the impact of financing expenses, realized gains/losses on foreign exchange hedges on prepayments, realized foreign exchange gains/losses on debt prepayments and restructuring expenses. EBITDA as defined by Penn West's debt agreements excludes the EBITDA contribution from assets sold in the prior 12 months and is used within Penn West's covenant calculations related to its syndicated bank facility and senior notes;
Funds flow from operations is funds flow but excluding the effects of financing related transactions from foreign exchange contracts and debt repayments/ pre-payments and is more representative of cash related to continuing operations, where funds flow is cash flow from operating activities before changes in non-cash working capital and decommissioning expenditures. Funds flow from operations is used to assess the company's ability to fund and planned capital programs. For additional information relating to funds flow from operations or funds flow, see our latest management's discussion and analysis which is available in Canada at www.sedar.com and in the United States at www.sec.gov;
Forward-Looking Statements
Certain statements contained in this document constitute forward-looking statements or information (collectively "forward-looking statements") within the meaning of the "safe harbour" provisions of applicable securities legislation. Forward-looking statements are typically identified by words such as "anticipate", "continue", "estimate", "expect", "forecast", "budget", "may", "will", "project", "could", "plan", "intend", "should", "believe", "outlook", "objective", "aim", "potential", "target", "pursue" and similar words suggesting future events or future performance. In addition, statements relating to "reserves" or "resources" are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions, that the reserves and resources described exist in the quantities predicted or estimated and can be profitably produced in the future. In particular, this document contains forward-looking statements pertaining to, without limitation, the following: our 2016 capital budget limiting our total expenditures to fund flow from operations, while driving down the cost structure; being prudent in limiting capital expenditures to protect the balance sheet and continuing to focus on the economics of every dollar spent even at the expense of maintaining production levels; intending to proceed only on opportunities with near term payout at current price levels; the expectation of full year operating costs to be below the bottom end of guidance and G&A to be within the guidance range; our plan to bring wells in the Cardium and Viking drilled in 2015 on production in the first quarter of 2016; continuing to find ways to make our company more resilient to falling prices, that the deep set of opportunities in our core plays will be there to create value for all Penn West Stakeholders and that we will be ready to get back to work when the commodity price recovers; us continuing to monitor the profitability of each of our fields; expected shut-ins of uneconomic core production during the first quarter of 2016; the impact that low commodity prices will have on equipment repair or replacement projects at non-core fields; the estimated deferral of projects impact on 2016 annual average production; our being in position to execute on repair opportunities as the project economics improve to levels that warrant such investment; our expected average annual production in 2016 and liquids weighting range (not taking into account potential dispositions) and base decline rate; limiting cash outlays in 2016 through controlling operating and G&A costs; identifying and implementing additional measures to reduce costs at our operated properties; expecting to see an approximate 20% decrease in absolute operating costs on a year over year, same field basis (not taking into account potential dispositions); our expectation for those measurements on operating costs and the average of those costs for full year 2016; continuing to ensure that our organizational structure reflects our expectation of reduced activity levels in the foreseeable future; our anticipation of a reduction in our annual general and administrative costs through initiatives already in progress and the average range of those costs for 2016; our expectation that approximately 30% of expenditures will be focused on operated development programs; completing work on wells drilled at the end of 2015 in the Viking and Cardium and funding our portion of the primary development program at our PROP joint venture net of amounts carried by our partner; not anticipating any new work on wells in the Viking or the Cardium in the first half of the year; our expectation that if current price levels persist, that our partners will seek to delay spending in some of those opportunities and to the extent they are delayed, that it would create additional flexibility within our capital program; that the majority of the remaining capital will be for the replacement of critical infrastructure at core properties in the Cardium; the expected levels of decommissioning expenditures; the commitment to limiting our combined capital budget and decommissioning expenditures to be within our funds flow from operations; remaining prudent within our pace of spending to maintain optionality throughout the year in response to further volatility in commodity prices, the belief that the non-core disposition program will help reduce capital requirements during the year and the continued discussions with potential buyers across our non-core asset base; our intent that proceeds from dispositions will be used to reduce our senior debt levels rather than to fund additional capital programs; our expected 2016 production guidance and controllable costs for the year (including operating costs and general and administrative costs) which we continue to focus our operational strategy on current commodity price levels and are using current strip pricing in our calculations, which we believe to be very conservative; and our belief that our enterprise continues to offer significant torque to a potential recovery in oil prices.
With respect to forward-looking statements contained in this document, we have made assumptions regarding, among other things: our ability to complete non-core asset sales and the terms and timing of any such sales; the economic returns that we anticipate realizing from expenditures made on our assets; future crude oil, natural gas liquids and natural gas prices and differentials between light, medium and heavy oil prices and Canadian, WTI and world oil and natural gas prices; future capital expenditure levels; future crude oil, natural gas liquids and natural gas production levels; drilling results; future exchange rates and interest rates; future taxes and royalties; the continued suspension of our dividend and our dividend reinvestment plan; our ability to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; our ability to obtain equipment in a timely manner to carry out development activities and the costs thereof; our ability to market our oil and natural gas successfully; our ability to obtain financing on acceptable terms, including our ability to renew or replace our syndicated bank facility; our ability to finance the repayment of our senior unsecured notes on maturity; and our ability to add production and reserves through our development and exploitation activities. In addition, many of the forward-looking statements contained in this document are located proximate to assumptions that are specific to those forward-looking statements, and such assumptions should be taken into account when reading such forward-looking statements.
Although we believe that the expectations reflected in the forward-looking statements contained in this document, and the assumptions on which such forward-looking statements are made, are reasonable, there can be no assurance that such expectations and assumptions will prove to be correct. Readers are cautioned not to place undue reliance on forward-looking statements included in this document, as there can be no assurance that the plans, intentions or expectations upon which the forward-looking statements are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur, which may cause our actual performance and financial results in future periods to differ materially from any estimates or projections of future performance or results expressed or implied by such forward-looking statements. These risks and uncertainties include, among other things: the possibility that we will be unable to complete all or some of our planned non-core asset dispositions; the possibility that we breach one or more of the financial covenants pursuant to our amending agreements with the syndicated banks and the holders of our senior secured notes; the possibility that we will not be able to realize anticipated costs savings as a result of our workforce reduction and other initiatives; the impact of weather conditions on seasonal demand; the impact of weather conditions on our ability to execute capital programs; the risk that we will be unable to execute our capital programs as planned without significant adverse impacts from various factors beyond our control, including weather, infrastructure access and delays in obtaining regulatory approvals and third party consents; risks inherent in oil and natural gas operations; uncertainties associated with estimating reserves and resources; competition for, among other things, capital, acquisitions of reserves, resources, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions or dispositions; geological, technical, drilling and processing problems; general economic and political conditions in Canada, the U.S. and globally; industry conditions, including fluctuations in the price of oil and natural gas, price differentials for crude oil and natural gas produced in Canada as compared to other markets, and transportation restrictions, including pipeline and railway capacity constraints; royalties payable in respect of our oil and natural gas production and changes to government royalty frameworks; changes in government regulation of the oil and natural gas industry, including environmental regulation; fluctuations in foreign exchange or interest rates; unanticipated operating events or environmental events that can reduce production or cause production to be shut-in or delayed, including extreme cold during winter months, wildfires and flooding; failure to obtain regulatory, industry partner and other third-party consents and approvals when required, including for acquisitions, dispositions and mergers; failure to realize the anticipated benefits of dispositions, acquisitions, joint ventures and partnerships, including those discussed herein; changes in tax and other laws that affect us and our securityholders; the potential failure of counterparties to honour their contractual obligations; stock market volatility and market valuations; the global supply and demand of crude oil; political uncertainty, including the risks of hostilities, in the petroleum producing regions of the world; and the other factors described in our public filings (including our Annual Information Form) available in Canada at www.sedar.com and in the United States at www.sec.gov. Readers are cautioned that this list of risk factors should not be construed as exhaustive.
The forward-looking statements contained in this document speak only as of the date of this document. Except as expressly required by applicable securities laws, we do not undertake any obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this document are expressly qualified by this cautionary statement.
SOURCE Penn West
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