Combined entity of Cabot Oil & Gas and Cimarex Energy, formed in 2021.
Coterra is a premier, diversified energy company based in Houston, Texas. We strive to be a leading producer, delivering returns with a commitment to sustainability leadership.
Project: Constitution Pipeline
Firm Commitment: 500,000 Dth/d
Project: Atlantic Sunrise Pipeline
Firm Commitment: 1,000,000 MMbtu/d
Project: PennEast Pipeline
Firm Commitment: 50,000 Dth/d
Project: Orion (formerly Marcellus to Milford) Project
Firm Commitment: 18,000 Dth/d
Project: Lackawanna Energy Center
Firm Commitment: 240,000 Dth/d
Project: Leidy South Transco Expansion Project
Firm Commitment: 250,000 Dth/d
Project: Auburn Gathering System Expansion
Firm Commitment: 150,000 Dth/d
COST: 256 $MM
VOLUMES: 20 Percent
HOUSTON, Feb. 4, 2021 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today provided an operational update for the fourth quarter and full-year 2020, reported its year-end 2020 estimated proved reserves, and announced 2021 guidance.
"Cabot Oil & Gas delivered another strong year operationally and financially in 2020, including its fifth consecutive year of positive free cash flow generation, despite the challenges presented by the COVID-19 pandemic and a depressed natural gas price environment, which resulted in the lowest natural gas price realizations in the Company's 31-year history as a public company," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "We remain positive on our outlook for significant free cash flow expansion this year, which is underpinned by improving fundamentals for natural gas supply and demand and lower capital spending year-over-year, allowing for an increase in our return of capital to shareholders and continued debt reduction in 2021."
Fourth Quarter and Full-Year 2020 Operational Update
Cabot expects its production for the fourth quarter of 2020 to be approximately 2,375 million cubic feet equivalent (Mmcfe) per day, exceeding the high-end of the Company's fourth quarter guidance range of 2,300 to 2,350 Mmcfe per day. Based on the expected production volumes for the fourth quarter, the Company expects its production for the full-year 2020 to be approximately 2,344 Mmcfe per day, exceeding the Company's full-year guidance range of 2,325 to 2,340 Mmcfe per day.
Natural gas price realizations, including the impact of hedges, are expected to be $1.90 per thousand cubic feet (Mcf) in the fourth quarter of 2020. Excluding the impact of hedges, natural gas price realizations for the fourth quarter are expected to be $1.89 per Mcf. For the full-year 2020, natural gas price realizations, including the impact of hedges, are expected to be $1.68 per Mcf. Excluding the impact of hedges, natural gas price realizations for the full-year are expected to be $1.64 per Mcf.
Cabot expects to have incurred approximately $106 million in capital expenditures associated with activity during the fourth quarter of 2020. Based on this anticipated level of spending during the quarter, the Company expects to have incurred approximately $570 million in capital expenditures associated with activity during the full-year of 2020, compared to the Company's 2020 capital program guidance of $575 million.
Year-End 2020 Estimated Proved Reserves
Cabot reported estimated year-end 2020 proved reserves of 13.7 trillion cubic feet equivalent (Tcfe), an increase of six percent over year-end 2019. The table below reconciles the components driving the 2020 reserve increase:
Estimated Proved Reserves Reconciliation (in billion cubic feet equivalent, Bcfe) | |||
Balance at December 31, 2019 | 12,903 | ||
Extensions, discoveries and other additions | 1,974 | ||
Revisions of prior estimates | (347) | ||
Production | (858) | ||
Balance at December 31, 2020 | 13,672 |
As of December 31, 2020, 100 percent of Cabot's year-end estimated proved reserves were natural gas and were located in the Marcellus Shale. Approximately 63 percent of the estimated year-end proved reserves were classified as proved developed and 37 percent were classified as proved undeveloped (PUD), including two percent of drilled and uncompleted PUDs.
Drill-bit finding and development (F&D) costs (non-GAAP) are expected to be $0.28 per thousand cubic feet equivalent (Mcfe), while all-sources F&D costs (non-GAAP) are expected to be $0.35 per Mcfe. "Our 2020 program delivered record-low drill-bit F&D costs, resulting in a year-over-year improvement in our all-sources F&D costs, despite a modest downward revision in our proved reserves due primarily to a downward performance revision related to certain proved developed producing properties and, to a lesser extent, PUD reserve reclassifications resulting from changes to the five-year development plan and pricing revisions," said Dinges.
2021 Guidance
Cabot today announced its guidance for 2021. The Company's operating plan for the year is expected to deliver an average net production rate of 2,350 Mmcfe per day from a capital program of $530 to $540 million, representing a six percent reduction in capital spending year-over-year at the midpoint of the range. Cabot has also provided its first quarter 2021 production guidance range of 2,250 to 2,300 Mmcfe per day. The sequential decline relative to the fourth quarter of 2020 is a result of the decrease in operating activity levels and capital spending during the second half of 2020. "Our plan for 2021 highlights our commitment to disciplined capital allocation and free cash flow generation with a focus on maintaining our production flat year-over-year despite the expectation for a higher natural gas price environment this year," commented Dinges. "Our maintenance capital program in 2021 is expected to provide Cabot with significant opportunities to return additional capital to shareholders as we continue to target a minimum return of capital of at least 50 percent of free cash flow annually, which the Company has far exceeded each of the last five years, in addition to retiring our 2021 debt maturities."
For further guidance on Cabot's natural gas pricing exposure by index, weighted-average natural gas price differential, and unit costs, please see the 2021 Guidance presentation in the Investor Relations section of the Company's website.
Fourth Quarter and Full-Year 2020 Conference Call
A conference call is scheduled for Friday, February 19, 2021, at 9:30 a.m. Eastern Time to discuss fourth quarter and full-year 2020 financial and operating results. The Company plans to issue its financial and operating results on Thursday, February 18, 2021 after the market closes. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward–looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, the continuing effects of the COVID-19 pandemic and the impact thereof on the Company's business, financial condition and results of operations, the availability of cash on hand and other sources of liquidity to fund our capital expenditures, the repayment of our debt maturities and our dividends, actions by, or disputes among or between, the Organization of Petroleum Exporting Countries and other producer countries, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Company's most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Finding and Development Costs
Drill-Bit Finding and Development Cost is defined as costs incurred in exploration and development activities as defined by GAAP divided by reserve extensions, discoveries and other additions. All-Sources Finding and Development Cost is defined as costs incurred in property acquisition, exploration and development activities, as defined by GAAP, divided by the total of reserve extensions, discoveries and other additions and revision of prior estimates. Drill-Bit Finding and Development Cost and All-Sources Finding and Development Cost are presented based on our belief that these non-GAAP measures are useful information to investors to evaluate how much it costs to add proved reserves. These calculations do not include the future development costs required for the development of proved undeveloped reserves and may not be comparable to similarly titled measurements used by other companies.
Year Ended December 31, | |||||||
2020 | 2019 | ||||||
Costs incurred in oil and gas property acquisition, exploration and development activities (In thousands) | |||||||
Exploration costs | $ | 15,419 | $ | 20,270 | |||
Development costs | 546,646 | 761,326 | |||||
Exploration and development costs (A) | 562,065 | 781,596 | |||||
Property acquisition costs, unproved | 5,821 | 6,072 | |||||
Total costs incurred (B) | 567,886 | 787,668 | |||||
Extensions, discoveries and other additions (Bcfe) (C) | 1,974 | 2,116 | |||||
Revision of prior estimates (Bcfe) (D) | (347) | 47 | |||||
Drill-bit finding and development costs ($ per Mcfe) (A) / (C) | $ | 0.28 | $ | 0.37 | |||
All-sources finding and development costs ($ per Mcfe) (B) / (C + D) | $ | 0.35 | $ | 0.36 |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 29, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the third quarter of 2020.
"2020 has proven to be the most challenging year for natural gas prices in the last 25 years, resulting from a multi-year trend of overcapitalization of both oil and natural gas assets across our industry," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "However, we are optimistic about the path forward as our industry as a whole has begun to adopt a similar philosophy on disciplined capital allocation that has been paramount to Cabot's strategy for years, which is centered on delivering strong corporate returns, generating free cash flow, returning capital to shareholders, and maintaining a strong balance sheet. We believe this capital discipline, along with rebounding demand largely driven by exports, will continue to move natural gas supply and demand toward a more sustainable balance, allowing Cabot to deliver a significant expansion of free cash flow in 2021 and beyond, while also increasing our return on and of capital."
Third Quarter 2020 Financial Results
Third quarter 2020 daily production was 2,406 million cubic feet equivalent (Mmcfe) per day (100 percent natural gas). During the third quarter of 2020, the Company drilled 13.0 net wells, completed 18.1 net wells, and placed 28.2 net wells on production.
Third quarter 2020 natural gas price realizations, including the impact of derivatives, were $1.57 per thousand cubic feet (Mcf), a decrease of 26 percent compared to the prior-year period. Excluding the impact of derivatives, third quarter 2020 natural gas price realizations were $1.51 per Mcf, representing a $0.47 discount to NYMEX settlement prices compared to a $0.34 discount in the prior-year period. Third quarter 2020 operating expenses (including interest expense) were $1.41 per thousand cubic feet equivalent (Mcfe), an improvement of one percent compared to the prior-year period.
Third quarter 2020 net loss was $15.0 million, or $0.04 per share, compared to net income of $90.4 million, or $0.22 per share, in the prior-year period. Third quarter 2020 adjusted net income (non-GAAP) was $37.3 million, or $0.09 per share, compared to $119.7 million, or $0.29 per share, in the prior-year period. Third quarter 2020 EBITDAX (non-GAAP) was $163.7 million, compared to $283.6 million in the prior-year period.
Third quarter 2020 net cash provided by operating activities was $129.1 million, compared to $270.9 million in the prior-year period. Third quarter 2020 discretionary cash flow (non-GAAP) was $146.9 million, compared to $275.5 million in the prior-year period. Third quarter 2020 free cash flow (non-GAAP) was ($0.3) million, compared to $72.4 million in the prior-year period. "Despite lower realized prices and the corresponding impact of strategic price-related curtailments on our production volumes, Cabot was able to deliver a free cash breakeven program during the third quarter," commented Dinges. "Based on the current NYMEX futures, we expect to generate between $125 and $150 million of free cash flow during the fourth quarter, resulting in our fifth consecutive year of positive free cash flow generation, despite the expectation for the lowest average annual NYMEX natural gas price on record since 1995."
Cabot incurred a total of $128.4 million of capital expenditures in the third quarter of 2020 including $119.2 million of drilling and facilities capital, $2.0 million of leasehold acquisition capital, and $7.2 million of other capital.
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and return on capital employed (ROCE).
Year-to-Date 2020 Financial Results
Daily equivalent production for the nine-month period ended September 30, 2020 was 2,333 Mmcfe per day (100 percent natural gas). During the nine-month period ended September 30, 2020, the Company drilled 49.2 net wells, completed 62.3 net wells, and placed 62.2 net wells on production.
Natural gas price realizations, including the impact of derivatives, were $1.60 per Mcf for the nine-month period ended September 30, 2020, a decrease of 38 percent compared to the prior-year period. For the nine-month period ended September 30, 2020, operating expenses (including interest expense) were $1.44 per Mcfe.
For the nine-month period ended September 30, 2020, net income was $69.3 million, or $0.17 per share, compared to $534.1 million, or $1.27 per share, in the prior-year period. Adjusted net income (non-GAAP) was $109.3 million, or $0.27 per share, compared to $578.0 million, or $1.38 per share, in the prior-year period. EBITDAX (non-GAAP) for the nine-month period ended September 30, 2020 was $489.6 million, compared to $1,108.3 million in the prior-year period.
For the nine-month period ended September 30, 2020, net cash provided by operating activities was $470.4 million, compared to $1,182.8 million in the prior-year period. Discretionary cash flow (non-GAAP) for the nine-month period ended September 30, 2020 was $464.6 million, compared to $1,083.2 million in the prior-year period. Free cash flow (non-GAAP) for the nine-month period ended September 30, 2020 was ($13.8) million, compared to $453.5 million in the prior-year period.
Cabot incurred a total of $463.9 million of capital expenditures during the nine-month period ended September 30, 2020 including $449.0 million of drilling and facilities capital, $3.3 million of leasehold acquisition capital, and $11.6 million of other capital.
Financial Position and Liquidity
As of September 30, 2020, Cabot had total debt of $1.2 billion and cash on hand of $0.2 million. The Company's debt-to-total capitalization ratio and debt-to-trailing twelve months EBITDAX ratio (non-GAAP) were 35.4 percent and 1.5x, respectively, compared to 36.2 percent and 0.9x as of December 31, 2019. As of September 30, 2020, the Company had $28.0 million outstanding under its credit facility, resulting in approximately $1.5 billion of liquidity. "While our leverage ratio has increased moderately throughout 2020 as a result of reduced EBITDAX due to lower price realizations, we anticipate a significant reduction in our leverage in 2021 through a combination of higher EBITDAX resulting from improved price realizations and lower absolute debt levels as we plan to utilize a portion of our expected free cash flow to retire our 2021 debt maturities," said Dinges.
Upper Marcellus Operations Update
Cabot has placed five Upper Marcellus wells on production during 2020, which have been producing for an average of 140 days. These wells are located across the eastern, western, and northern areas of the Company's acreage position and are offset to currently producing Lower Marcellus wells. Based on the production history to date, on average these wells are currently exceeding the estimated ultimate recovery (EUR) of 2.7 billion cubic feet (Bcf) per thousand lateral feet that was reported at year-end for Cabot's 2018 and 2019 Upper Marcellus wells. "We believe these results continue to demonstrate the productivity of this distinct, economic interval across our 173,000 net acre position in the core of the dry gas window in northeast Pennsylvania," noted Dinges. "We plan to continue to allocate a modest amount of capital to the Upper Marcellus annually as we continue to optimize our well design and lateral placement across this interval, with the intent of moving to full development of our Upper Marcellus inventory at the tail end of this decade. We expect to develop the Upper Marcellus at an average lateral length greater than 10,000 feet, which would provide significant well cost savings, further improving the economics of our Upper Marcellus inventory."
Fourth Quarter / Full-Year 2020 and Preliminary 2021 Guidance
Cabot has reaffirmed its fourth quarter 2020 production guidance range of 2,300 to 2,350 Mmcfe per day, which includes the impact of previously announced price-related curtailments during the quarter. The Company has also reaffirmed its full-year 2020 production guidance range of 2,325 to 2,340 Mmcfe per day based on a capital program of $575 million.
Cabot has also provided preliminary 2021 production guidance of 2,350 Mmcfe per day from a capital program of $530 to $540 million, representing a seven percent reduction in capital spending year-over-year at the midpoint of the range. "Despite the expectation for higher price realizations and cash flow in 2021, our capital allocation priorities remain focused on maintaining our current production levels, funding our current dividend, retiring our 2021 debt maturities, and opportunistically returning incremental free cash flow to shareholders as we continue to target a minimum return of capital of at least 50 percent of free cash flow annually," stated Dinges. "While we will continue to analyze the natural gas market outlook as we evaluate the potential for disciplined investment in modest levels of growth capital in the future, it is our belief that the natural gas price futures for 2022 and beyond, which are currently in backwardation, do not warrant incremental levels of capital investment above our current maintenance capital requirements at this time."
Inaugural Sustainability Accounting Standards Board (SASB) Report
Cabot today issued its inaugural SASB report, highlighting the Company's commitment to environmental responsibility, workforce health and safety, business ethics, and risk management. The report is available at www.cabotog.com/corporate-responsibility. "At Cabot, we strive not only to be a leading independent producer of natural gas, but to also be a leader in safe, responsible operations, to minimize our impact on the environment, and to be a valued partner to our employees and communities," commented Dinges. "We believe this commitment, along with our operational success, continues to create value for our shareholders and other stakeholders in our communities. With the issuance of this inaugural SASB report, we are adding transparency into our environmental, social and governance programs, further highlighting our focus on sustainable and responsible operations."
Conference Call Webcast
A conference call is scheduled for Friday, October 30, 2020, at 9:30 a.m. Eastern Time to discuss third quarter 2020 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, the continuing effects of the COVID-19 pandemic and the impact thereof on the Company's business, financial condition and results of operations, the availability of cash on hand and other sources of liquidity to fund our capital expenditures, the repayment of our debt maturities and our dividends, actions by, or disputes among or between, the Organization of Petroleum Exporting Countries and other producer countries, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Company's most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
2020 | 2019 | 2020 | 2019 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 221.4 | 220.7 | 639.2 | 639.3 | |||||||||||
Equivalent production (Bcfe) | 221.4 | 220.7 | 639.2 | 639.3 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,406 | 2,399 | 2,333 | 2,342 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 1.57 | $ | 2.11 | $ | 1.60 | $ | 2.56 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 1.51 | $ | 1.89 | $ | 1.55 | $ | 2.38 | |||||||
AVERAGE UNIT COSTS ($/Mcfe)(1) | |||||||||||||||
Direct operations | $ | 0.09 | $ | 0.09 | $ | 0.09 | $ | 0.09 | |||||||
Transportation and gathering | 0.66 | 0.66 | 0.67 | 0.66 | |||||||||||
Taxes other than income | 0.02 | 0.02 | 0.02 | 0.02 | |||||||||||
Exploration | 0.02 | 0.02 | 0.02 | 0.02 | |||||||||||
Depreciation, depletion and amortization | 0.45 | 0.50 | 0.46 | 0.47 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.06 | 0.07 | 0.07 | 0.08 | |||||||||||
Stock-based compensation | 0.05 | 0.01 | 0.06 | 0.04 | |||||||||||
Interest expense | 0.06 | 0.06 | 0.07 | 0.06 | |||||||||||
$ | 1.41 | $ | 1.43 | $ | 1.44 | $ | 1.44 | ||||||||
WELLS DRILLED (2) | |||||||||||||||
Gross | 14 | 22 | 55 | 71 | |||||||||||
Net | 13.0 | 22.0 | 49.2 | 71.0 | |||||||||||
WELLS COMPLETED (2) | |||||||||||||||
Gross | 22 | 29 | 71 | 71 | |||||||||||
Net | 18.1 | 29.0 | 62.3 | 71.0 |
_______________________________________________________________________________ | ||
(1) | Total unit cost may differ from the sum of the individual costs due to rounding. | |
(2) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2020 | 2019 | 2020 | 2019 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 333,256 | $ | 418,133 | $ | 991,882 | $ | 1,521,789 | |||||||
(Loss) gain on derivative instruments | (42,253) | 11,060 | 17,783 | 82,966 | |||||||||||
Other | 38 | (82) | 181 | 154 | |||||||||||
291,041 | 429,111 | 1,009,846 | 1,604,909 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 20,197 | 19,181 | 54,864 | 55,608 | |||||||||||
Transportation and gathering | 146,982 | 145,681 | 425,563 | 424,703 | |||||||||||
Taxes other than income | 3,615 | 4,607 | 10,705 | 14,094 | |||||||||||
Exploration | 3,900 | 4,481 | 10,669 | 15,029 | |||||||||||
Depreciation, depletion and amortization | 99,649 | 110,889 | 294,406 | 299,294 | |||||||||||
General and administrative (excluding stock-based compensation) | 12,890 | 16,272 | 44,901 | 48,398 | |||||||||||
Stock-based compensation(1) | 11,372 | 2,119 | 35,956 | 23,972 | |||||||||||
298,605 | 303,230 | 877,064 | 881,098 | ||||||||||||
Earnings (loss) on equity method investments | — | 3,860 | (59) | 11,194 | |||||||||||
Gain (loss) on sale of assets | 31 | 36 | (139) | (1,464) | |||||||||||
(LOSS) INCOME FROM OPERATIONS | (7,533) | 129,777 | 132,584 | 733,541 | |||||||||||
Interest expense, net | 14,389 | 13,554 | 43,143 | 40,302 | |||||||||||
Other expense | 57 | 143 | 171 | 430 | |||||||||||
(Loss) income before income taxes | (21,979) | 116,080 | 89,270 | 692,809 | |||||||||||
Income tax (benefit) expense | (7,018) | 25,722 | 19,947 | 158,679 | |||||||||||
NET (LOSS) INCOME | $ | (14,961) | $ | 90,358 | $ | 69,323 | $ | 534,130 | |||||||
(Loss) earnings per share - Basic | $ | (0.04) | $ | 0.22 | $ | 0.17 | $ | 1.27 | |||||||
Weighted-average common shares outstanding | 398,580 | 412,456 | 398,500 | 419,199 |
_______________________________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | September 30, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 322,552 | $ | 568,248 | |||
Properties and equipment, net (Successful efforts method) | 4,034,680 | 3,855,706 | |||||
Other assets | 62,073 | 63,291 | |||||
$ | 4,419,305 | $ | 4,487,245 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 197,928 | $ | 241,034 | |||
Current portion of long-term debt | 188,000 | 87,000 | |||||
Long-term debt, net (excluding current maturities) | 973,712 | 1,133,025 | |||||
Deferred income taxes | 748,489 | 702,104 | |||||
Other liabilities | 192,688 | 172,595 | |||||
Stockholders' equity | 2,118,488 | 2,151,487 | |||||
$ | 4,419,305 | $ | 4,487,245 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net (loss) income | $ | (14,961) | $ | 90,358 | $ | 69,323 | $ | 534,130 | |||||||
Depreciation, depletion and amortization | 99,649 | 110,889 | 294,406 | 299,294 | |||||||||||
Deferred income tax (benefit) expense | (5,576) | 36,350 | 46,513 | 188,997 | |||||||||||
(Gain) loss on sale of assets | (31) | (36) | 139 | 1,464 | |||||||||||
Exploratory dry hole cost | — | — | 2,011 | 16 | |||||||||||
Loss (gain) on derivative instruments | 42,253 | (11,060) | (17,783) | (82,966) | |||||||||||
Net cash received in settlement of derivative instruments | 14,106 | 46,555 | 33,529 | 114,931 | |||||||||||
Stock-based compensation and other | 10,741 | 1,662 | 34,204 | 22,720 | |||||||||||
Income charges not requiring cash | 733 | 754 | 2,293 | 4,635 | |||||||||||
Changes in assets and liabilities | (17,854) | (4,598) | 5,758 | 99,590 | |||||||||||
Net cash provided by operating activities | 129,060 | 270,874 | 470,393 | 1,182,811 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (147,239) | (199,196) | (478,422) | (620,696) | |||||||||||
Proceeds from sale of assets | 60 | 55 | 335 | 2,401 | |||||||||||
Investment in equity method investments | — | (3,846) | (35) | (8,977) | |||||||||||
Distribution of investment from equity method investments | — | 898 | — | 1,656 | |||||||||||
Proceeds from sale of equity method investments | — | — | (9,424) | — | |||||||||||
Net cash used in investing activities | (147,179) | (202,089) | (487,546) | (625,616) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | (59,000) | — | (59,000) | (7,000) | |||||||||||
Treasury stock repurchases | — | (190,808) | — | (347,446) | |||||||||||
Dividends paid | (39,857) | (37,025) | (119,532) | (104,722) | |||||||||||
Tax withholdings on vesting of stock awards | (18) | (30) | (6,350) | (10,587) | |||||||||||
Capitalized debt issuance costs | — | — | — | (7,411) | |||||||||||
Net cash used in financing activities | (98,875) | (227,863) | (184,882) | (477,166) | |||||||||||
Net (decrease) increase in cash, cash equivalents and restricted cash | $ | (116,994) | $ | (159,078) | $ | (202,035) | $ | 80,029 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net (Loss) Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Adjusted Net Income is defined as net income or loss plus gain and loss on sale of assets, gain and loss on derivative instruments, stock-based compensation expense, severance expense, interest expense related to income tax reserves and tax effect on selected items. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income or loss and earnings or loss per share, as defined by GAAP.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2020 | 2019 | 2020 | 2019 | |||||||||||
As reported - net (loss) income | $ | (14,961) | $ | 90,358 | $ | 69,323 | $ | 534,130 | |||||||
Reversal of selected items: | |||||||||||||||
(Gain) loss on sale of assets | (31) | (36) | 139 | 1,464 | |||||||||||
Loss on derivative instruments(1) | 56,359 | 35,495 | 15,746 | 31,965 | |||||||||||
Stock-based compensation expense | 11,372 | 2,119 | 35,956 | 23,972 | |||||||||||
Severance expense | — | 398 | — | 2,521 | |||||||||||
Interest expense related to income tax reserves | — | — | — | (3,052) | |||||||||||
Tax effect on selected items | (15,442) | (8,672) | (11,825) | (12,986) | |||||||||||
Adjusted net income | $ | 37,297 | $ | 119,662 | $ | 109,339 | $ | 578,014 | |||||||
As reported - (loss) earnings per share | $ | (0.04) | $ | 0.22 | $ | 0.17 | $ | 1.27 | |||||||
Per share impact of selected items | 0.13 | 0.07 | 0.10 | 0.11 | |||||||||||
Adjusted earnings per share | $ | 0.09 | $ | 0.29 | $ | 0.27 | $ | 1.38 | |||||||
Weighted-average common shares outstanding | 398,580 | 412,456 | 398,500 | 419,199 |
_______________________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in (Loss) gain on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as Adjusted Net Income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our profitability and the efficiency with which we have employed capital over time. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income or loss, as defined by GAAP.
Twelve Months Ended September 30, | |||||||
(In thousands) | 2020 | 2019 | |||||
Interest expense, net | $ | 57,793 | $ | 55,926 | |||
Interest expense related to income tax reserves (1) | — | 3,590 | |||||
Tax benefit | (13,183) | (13,590) | |||||
After-tax interest expense, net (A) | 44,610 | 45,926 | |||||
As reported - net income | 216,263 | 809,174 | |||||
Adjustments to as reported - net income, net of tax | 13,826 | 4,622 | |||||
Adjusted net income (B) | 230,089 | 813,796 | |||||
Adjusted net income before interest expense, net (A + B) | $ | 274,699 | $ | 859,722 | |||
Total debt - beginning of twelve month period | $ | 1,219,790 | $ | 1,285,848 | |||
Stockholders' equity - beginning of twelve month period | 2,213,576 | 2,094,147 | |||||
Capital employed - beginning of twelve month period | 3,433,366 | 3,379,995 | |||||
Total debt - end of twelve month period | 1,161,712 | 1,219,790 | |||||
Stockholders' equity - end of twelve month period | 2,118,488 | 2,213,576 | |||||
Capital employed - end of twelve month period | 3,280,200 | 3,433,366 | |||||
Average capital employed (C) | $ | 3,356,783 | $ | 3,406,681 | |||
Return on average capital employed (ROCE) (A + B) / C | 8.2 | % | 25.2 | % |
_______________________________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, return capital to shareholders through dividends and share repurchases, and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income or loss, as defined by GAAP, or as a measure of liquidity.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income or loss, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Nine Months Ended | |||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | ||||||||||||
Net cash provided by operating activities | $ | 129,060 | $ | 270,874 | $ | 470,393 | $ | 1,182,811 | ||||||||
Changes in assets and liabilities | 17,854 | 4,598 | (5,758) | (99,590) | ||||||||||||
Discretionary cash flow | 146,914 | 275,472 | 464,635 | 1,083,221 | ||||||||||||
Capital expenditures | (147,239) | (199,196) | (478,422) | (620,696) | ||||||||||||
Investment in equity method investments | — | (3,846) | (35) | (8,977) | ||||||||||||
Free cash flow | $ | (325) | $ | 72,430 | $ | (13,822) | $ | 453,548 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income or loss plus interest expense, other expense, income tax expense and benefit, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income or loss, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
Net (loss) income | $ | (14,961) | $ | 90,358 | $ | 69,323 | $ | 534,130 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 14,389 | 13,554 | 43,143 | 40,302 | |||||||||||
Other expense | 57 | 143 | 171 | 430 | |||||||||||
Income tax (benefit) expense | (7,018) | 25,722 | 19,947 | 158,679 | |||||||||||
Depreciation, depletion and amortization | 99,649 | 110,889 | 294,406 | 299,294 | |||||||||||
Exploration | 3,900 | 4,481 | 10,669 | 15,029 | |||||||||||
(Gain) loss on sale of assets | (31) | (36) | 139 | 1,464 | |||||||||||
Non-cash gain (loss) on derivative instruments | 56,359 | 35,495 | 15,746 | 31,965 | |||||||||||
(Earnings) loss on equity method investments | — | (3,860) | 59 | (11,194) | |||||||||||
Equity method investment distributions | — | 4,758 | — | 14,266 | |||||||||||
Stock-based compensation | 11,372 | 2,119 | 35,956 | 23,972 | |||||||||||
EBITDAX | $ | 163,716 | $ | 283,623 | $ | 489,559 | $ | 1,108,337 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | September 30, | December 31, | |||||
Current portion of long-term debt | $ | 188,000 | $ | 87,000 | |||
Long-term debt, net | 973,712 | 1,133,025 | |||||
Total debt | $ | 1,161,712 | $ | 1,220,025 | |||
Stockholders' equity | 2,118,488 | 2,151,487 | |||||
Total capitalization | $ | 3,280,200 | $ | 3,371,512 | |||
Total debt | $ | 1,161,712 | $ | 1,220,025 | |||
Less: Cash and cash equivalents | (170) | (200,227) | |||||
Net debt | $ | 1,161,542 | $ | 1,019,798 | |||
Net debt | $ | 1,161,542 | $ | 1,019,798 | |||
Stockholders' equity | 2,118,488 | 2,151,487 | |||||
Total adjusted capitalization | $ | 3,280,030 | $ | 3,171,285 | |||
Total debt to total capitalization ratio | 35.4 | % | 36.2 | % | |||
Less: Impact of cash and cash equivalents | — | % | 4.0 | % | |||
Net debt to adjusted capitalization ratio | 35.4 | % | 32.2 | % |
Capital Expenditures
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
Cash paid for capital expenditures | $ | 147,239 | $ | 199,196 | $ | 478,422 | $ | 620,696 | |||||||
Change in accrued capital costs | (18,883) | (1,732) | (12,486) | 1,436 | |||||||||||
Exploratory dry hole cost | — | — | (2,011) | (16) | |||||||||||
Capital expenditures | $ | 128,356 | $ | 197,464 | $ | 463,925 | $ | 622,116 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-third-quarter-2020-results-301163434.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 28, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of ten cents ($0.10) per share on the Company's common stock. The dividend will be paid on November 23, 2020 to all shareholders of record as of the close of business on November 12, 2020.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-301162314.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 7, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today provided an operational update for the third quarter of 2020 and announced updated 2020 guidance.
Third Quarter 2020 Operational Update
"On September 18, 2020, Cabot commenced a strategic curtailment program in response to weakness in regional natural gas prices throughout Appalachia, resulting in an estimated average daily curtailment of approximately 372 million cubic feet equivalent (Mmcfe) per day of gross production during the last 13 days of the quarter," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "While our low cost structure affords us the opportunity to deliver cash margins even in the lows of the natural gas price cycle, we continue to evaluate all opportunities to enhance value for our shareholders including the decision to temporarily forgo production in anticipation of generating higher margins for our volumes in the near future. Despite our price-related curtailments in September, Cabot's third quarter production still fell within our previously disclosed guidance range."
Cabot expects production for the third quarter of 2020 to be approximately 2,406 Mmcfe per day. Natural gas price realizations, including the impact of derivatives, are expected to be $1.57 per thousand cubic feet (Mcf) in the third quarter of 2020. Excluding the impact of derivatives, natural gas price realizations for the quarter are expected to be $1.51 per Mcf, representing a $0.47 discount to NYMEX settlement prices.
Updated 2020 Guidance
Taking into account the anticipated impact of continued price-related curtailments in October, which have averaged an estimated 450 Mmcfe per day of gross production month-to-date, Cabot has provided a fourth quarter 2020 production guidance range of 2,300 to 2,350 Mmcfe per day, resulting in an updated full-year 2020 production guidance range of 2,325 to 2,340 Mmcfe per day based on a capital program of $575 million. "While natural gas prices across North America currently remain challenged due to lower seasonal demand during the shoulder season and storage levels that are nearing capacity, we remain optimistic about the improving natural gas supply and demand outlook heading into 2021, which has resulted in a significant increase in the 2021 natural gas price futures since late July," noted Dinges. "This improvement in the natural gas price outlook is expected to result in a meaningful expansion in Cabot's free cash flow next year, which will allow the Company to utilize excess free cash flow for increased return of capital to shareholders and the repayment of our 2021 debt maturities."
2021 NYMEX Hedging Update
Cabot recently initiated its 2021 hedging position as a result of the improvement in the NYMEX futures for 2021. Currently, the Company has 138.5 million Mmbtu of NYMEX natural gas collars with a weighted average floor price of $2.63 per Mmbtu and a weighted average ceiling price of $3.01 per Mmbtu. The Company also has 18.3 million Mmbtu of NYMEX natural gas swaps with a weighted average price of $2.74 per Mmbtu. "Given the improvement in the 2021 NYMEX futures during the third quarter, we have implemented a price risk management strategy for 2021 to mitigate downside risk while still offering upside potential," commented Dinges. "Our hedging strategy continues to be focused on opportunistically locking in downside protection while maintaining some level of market price exposure if natural gas prices continue to move higher as a result of improving natural gas balances."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward–looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, the continuing effects of the COVID-19 pandemic and the impact thereof on the Company's business, financial condition and results of operations, the availability of cash on hand and other sources of liquidity to fund our capital expenditures, the repayment of our debt maturities and our dividends, actions by, or disputes among or between, the Organization of Petroleum Exporting Countries and other producer countries, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Company's most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-provides-operational-update-301147978.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 1, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it plans to release its financial and operating results on Thursday, October 29, 2020, after market closes. The Company will host its third quarter 2020 earnings conference call on Friday, October 30, 2020 at 9:30 a.m. Eastern Time.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-third-quarter-2020-earnings-release-and-conference-call-301142360.html
SOURCE Cabot Oil & Gas Corporation
BENSALEM, Pa., Sept. 30, 2020 /PRNewswire/ -- Law Offices of Howard G. Smith reminds investors of the upcoming October 13, 2020 deadline to file a lead plaintiff motion in the class action filed on behalf of investors who acquired Cabot Oil & Gas Corporation ("Cabot Oil" or "the Company") (NYSE: COG) securities between October 23, 2015 and June 12, 2020, inclusive (the "Class Period").
Investors suffering losses on their Cabot Oil investments are encouraged to contact the Law Offices of Howard G. Smith to discuss their legal rights in this class action at 888-638-4847 or by email to howardsmith@howardsmithlaw.com.
On July 26, 2019, the Company disclosed that it had received two proposed Consent Order and Agreements related to two Notices of Violation it had received from the Pennsylvania Department of Environmental Protection in 2017 for failure to prevent the migration of gas into fresh groundwater sources in the area surrounding Susquehanna County, Pennsylvania.
On this news, Cabot Oil's share price fell $2.63, or over 12%, to close at $19.16 per share on July 26, 2019.
On June 15, 2020, following a grand jury investigation, the Pennsylvania attorney general's office charged Cabot Oil with 15 criminal counts due to its failure to fix faulty gas wells, which polluted Pennsylvania's water supplies through stray gas migration.
On this news, Cabot Oil's share price fell $0.67 per share, or 3.34%, to close at $19.40 per share on June 15, 2020.
The complaint alleges that throughout the Class Period, Defendants made materially false and/or misleading statements, as well as failed to disclose material adverse facts about the Company's business, operations, and prospects. Specifically, Defendants failed to disclose to investors: (1) that the Company had inadequate environmental controls and procedures and/or failed to properly mitigate known issues related to those controls and procedures; (2) as a result, the Company, among other issues, failed to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration; (3) that the foregoing was foreseeably likely to subject the Company to increased governmental scrutiny and enforcement, as well as increased reputational and financial harm; (4) that Defendants continually downplayed its potential civil and/or criminal liabilities with respect to such environmental matters; and (5) as a result, the Company's public statements were materially false and misleading at all relevant times.
If you purchased or otherwise acquired Cabot Oil securities, you may move the Court no later than October 13, 2020 to ask the Court to appoint you as lead plaintiff if you meet certain legal requirements. To be a member of the class action you need not take any action at this time; you may retain counsel of your choice or take no action and remain an absent member of the class action. If you wish to learn more about this class action, or if you have any questions concerning this announcement or your rights or interests with respect to these matters, please contact Howard G. Smith, Esquire, of Law Offices of Howard G. Smith, 3070 Bristol Pike, Suite 112, Bensalem, Pennsylvania 19020 by telephone at (215) 638-4847, toll-free at (888) 638-4847, or by email to howardsmith@howardsmithlaw.com, or visit our website at www.howardsmithlaw.com.
This press release may be considered Attorney Advertising in some jurisdictions under the applicable law and ethical rules.
Contacts
Law Offices of Howard G. Smith
Howard G. Smith, Esquire
215-638-4847
888-638-4847
howardsmith@howardsmithlaw.com
www.howardsmithlaw.com
SOURCE Law Offices of Howard G. Smith
NEW YORK, Sept. 29, 2020 /PRNewswire/ -- Pomerantz LLP announces that a class action lawsuit has been filed against Cabot Oil & Gas Corporation ("Cabot" or the "Company") (NYSE: COG) and certain of its officers. The class action, filed in United States District Court for the Southern District of Texas, Houston Division, and docketed under 20-cv-02827, is on behalf of a class consisting of all persons other than Defendants who purchased or otherwise acquired Cabot securities between October 23, 2015, and June 12, 2020, both dates inclusive (the "Class Period"), seeking to recover damages caused by Defendants' violations of the federal securities laws and to pursue remedies under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 (the "Exchange Act") and Rule 10b-5 promulgated thereunder, against the Company and certain of its top officials.
If you are a shareholder who purchased Cabot securities during the class period, you have until October 13, 2020, to ask the Court to appoint you as Lead Plaintiff for the class. A copy of the Complaint can be obtained at www.pomerantzlaw.com. To discuss this action, contact Robert S. Willoughby at newaction@pomlaw.com or 888.476.6529 (or 888.4-POMLAW), toll-free, Ext. 7980. Those who inquire by e-mail are encouraged to include their mailing address, telephone number, and the number of shares purchased.
[Click here for information about joining the class action]
Cabot is an independent oil and gas company that explores, exploits, develops, produces, and markets oil and gas properties in the U.S.
Cabot primarily focuses its oil and gas efforts on the Marcellus Shale located in Susquehanna County, Pennsylvania. Cabot's gas procuring activities in Pennsylvania have been the subject of controversy for over a decade, with the Company repeatedly denying any responsibility for environmental damage observed in the state.
The complaint alleges that throughout the Class Period, Defendants made materially false and misleading statements regarding the Company's business, operational, and compliance policies. Specifically, Defendants made false and/or misleading statements and/or failed to disclose that: (i) Cabot had inadequate environmental controls and procedures and/or failed to properly mitigate known issues related to those controls and procedures; (ii) as a result, Cabot, among other issues, failed to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration; (iii) the foregoing was foreseeably likely to subject Cabot to increased governmental scrutiny and enforcement, as well as increased reputational and financial harm; (iv) Cabot continually downplayed its potential civil and/or criminal liabilities with respect to such environmental matters; and (v) as a result, the Company's public statements were materially false and misleading at all relevant times.
On July 26, 2019, during intraday trading hours, Cabot filed a quarterly report on Form 10-Q with the Securities and Exchange Commission, reporting the Company's financial and operating results for the quarter ended June 30, 2019 (the "2Q19 10-Q"). The 2Q19 10-Q disclosed that the Company had received two proposed Consent Order and Agreements ("CO&As") related to two Notices of Violation ("NOVs") it had received from the Pennsylvania Department of Environmental Protection ("PaDEP") back in June and November 2017, respectively, for failure to prevent the migration of gas into fresh groundwater sources in the area surrounding Susquehanna County, Pennsylvania.
Following the release of the 2Q19 10-Q, Cabot's stock price fell $2.63 per share, or 12.07%, to close at $19.16 per share on July 26, 2019.
Then, on June 15, 2020, during pre-market hours, following a grand jury investigation, the Pennsylvania attorney general's office charged Cabot with fifteen criminal counts arising from its failure to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration.
On this news, Cabot's stock price fell $0.67 per share, or 3.34%, to close at $19.40 per share on June 15, 2020.
The Pomerantz Firm, with offices in New York, Chicago, Los Angeles, and Paris is acknowledged as one of the premier firms in the areas of corporate, securities, and antitrust class litigation. Founded by the late Abraham L. Pomerantz, known as the dean of the class action bar, the Pomerantz Firm pioneered the field of securities class actions. Today, more than 80 years later, the Pomerantz Firm continues in the tradition he established, fighting for the rights of the victims of securities fraud, breaches of fiduciary duty, and corporate misconduct. The Firm has recovered numerous multimillion-dollar damages awards on behalf of class members. See www.pomerantzlaw.com.
CONTACT:
Robert S. Willoughby
Pomerantz LLP
rswilloughby@pomlaw.com
SOURCE Pomerantz LLP
NEW YORK, Sept. 14, 2020 /PRNewswire/ -- Pomerantz LLP announces that a class action lawsuit has been filed against Cabot Oil & Gas Corporation ("Cabot" or the "Company") (NYSE: COG) and certain of its officers. The class action, filed in United States District Court for the Southern District of Texas, Houston Division, and docketed under 20-cv-02827, is on behalf of a class consisting of all persons other than Defendants who purchased or otherwise acquired Cabot securities between October 23, 2015, and June 12, 2020, both dates inclusive (the "Class Period"), seeking to recover damages caused by Defendants' violations of the federal securities laws and to pursue remedies under Sections 10(b) and 20(a) of the Securities Exchange Act of 1934 (the "Exchange Act") and Rule 10b-5 promulgated thereunder, against the Company and certain of its top officials.
If you are a shareholder who purchased Cabot securities during the class period, you have until October 13, 2020, to ask the Court to appoint you as Lead Plaintiff for the class. A copy of the Complaint can be obtained at www.pomerantzlaw.com. To discuss this action, contact Robert S. Willoughby at newaction@pomlaw.com or 888.476.6529 (or 888.4-POMLAW), toll-free, Ext. 7980. Those who inquire by e-mail are encouraged to include their mailing address, telephone number, and the number of shares purchased.
[Click here for information about joining the class action]
Cabot is an independent oil and gas company that explores, exploits, develops, produces, and markets oil and gas properties in the U.S.
Cabot primarily focuses its oil and gas efforts on the Marcellus Shale located in Susquehanna County, Pennsylvania. Cabot's gas procuring activities in Pennsylvania have been the subject of controversy for over a decade, with the Company repeatedly denying any responsibility for environmental damage observed in the state.
The complaint alleges that throughout the Class Period, Defendants made materially false and misleading statements regarding the Company's business, operational, and compliance policies. Specifically, Defendants made false and/or misleading statements and/or failed to disclose that: (i) Cabot had inadequate environmental controls and procedures and/or failed to properly mitigate known issues related to those controls and procedures; (ii) as a result, Cabot, among other issues, failed to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration; (iii) the foregoing was foreseeably likely to subject Cabot to increased governmental scrutiny and enforcement, as well as increased reputational and financial harm; (iv) Cabot continually downplayed its potential civil and/or criminal liabilities with respect to such environmental matters; and (v) as a result, the Company's public statements were materially false and misleading at all relevant times.
On July 26, 2019, during intraday trading hours, Cabot filed a quarterly report on Form 10-Q with the Securities and Exchange Commission, reporting the Company's financial and operating results for the quarter ended June 30, 2019 (the "2Q19 10-Q"). The 2Q19 10-Q disclosed that the Company had received two proposed Consent Order and Agreements ("CO&As") related to two Notices of Violation ("NOVs") it had received from the Pennsylvania Department of Environmental Protection ("PaDEP") back in June and November 2017, respectively, for failure to prevent the migration of gas into fresh groundwater sources in the area surrounding Susquehanna County, Pennsylvania.
Following the release of the 2Q19 10-Q, Cabot's stock price fell $2.63 per share, or 12.07%, to close at $19.16 per share on July 26, 2019.
Then, on June 15, 2020, during pre-market hours, following a grand jury investigation, the Pennsylvania attorney general's office charged Cabot with fifteen criminal counts arising from its failure to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration.
On this news, Cabot's stock price fell $0.67 per share, or 3.34%, to close at $19.40 per share on June 15, 2020.
The Pomerantz Firm, with offices in New York, Chicago, Los Angeles, and Paris is acknowledged as one of the premier firms in the areas of corporate, securities, and antitrust class litigation. Founded by the late Abraham L. Pomerantz, known as the dean of the class action bar, the Pomerantz Firm pioneered the field of securities class actions. Today, more than 80 years later, the Pomerantz Firm continues in the tradition he established, fighting for the rights of the victims of securities fraud, breaches of fiduciary duty, and corporate misconduct. The Firm has recovered numerous multimillion-dollar damages awards on behalf of class members. See www.pomerantzlaw.com.
CONTACT:
Robert S. Willoughby
Pomerantz LLP
rswilloughby@pomlaw.com
SOURCE Pomerantz LLP
HOUSTON, July 30, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second quarter of 2020.
"Cabot Oil & Gas demonstrated its continued ability to deliver profitability during this global pandemic, which has contributed to a historically-low natural gas price environment, resulting in the lowest quarterly average NYMEX price on record since the third quarter of 1995," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "We anticipate that the improving demand outlook for natural gas, in conjunction with accelerated structural declines in supply resulting from significant activity cuts across all onshore basins, will provide tailwinds for natural gas prices this winter."
Second Quarter 2020 Financial Results
Second quarter 2020 daily production was 2,229 million cubic feet equivalent (Mmcfe) per day (100 percent natural gas), exceeding the high-end of the Company's guidance range. During the second quarter of 2020, the Company drilled 14.2 net wells, completed 31.2 net wells, and placed 25.0 net wells on production.
Second quarter 2020 natural gas price realizations, including the impact of derivatives, were $1.52 per thousand cubic feet (Mcf), a decrease of 33 percent compared to the prior-year period. Excluding the impact of derivatives, second quarter 2020 natural gas price realizations represented a $0.30 discount to NYMEX settlement prices compared to a $0.44 discount in the prior-year period. Second quarter 2020 operating expenses (including interest expense) were $1.44 per thousand cubic feet equivalent (Mcfe).
Second quarter 2020 net income was $30.4 million, or $0.08 per share, compared to $181.0 million, or $0.43 per share, in the prior-year period. Second quarter 2020 adjusted net income (non-GAAP) was $18.0 million, or $0.05 per share, compared to $150.6 million, or $0.36 per share, in the prior-year period. Second quarter 2020 EBITDAX (non-GAAP) was $136.9 million, compared to $311.1 million in the prior-year period.
Second quarter 2020 net cash provided by operating activities was $136.4 million, compared to $326.7 million in the prior-year period. Second quarter 2020 discretionary cash flow (non-GAAP) was $119.2 million, compared to $301.9 million in the prior-year period. Second quarter 2020 free cash flow (non-GAAP) was ($63.3) million, compared to $72.7 million in the prior-year period. "Lower realized prices during the second quarter, coupled with our decision to sequentially decline production volumes into a lower price environment associated with the spring shoulder season, resulted in our first free cash flow deficit since the second quarter of 2018," commented Dinges. "Based on the current NYMEX futures, we anticipate a significant expansion in our free cash flow during the second half of 2020 driven by an improvement in realized prices, higher production volumes, and lower capital expenditures, allowing Cabot to deliver positive free cash flow for a fifth consecutive year."
Cabot incurred a total of $175.3 million of capital expenditures in the second quarter of 2020 including $171.8 million of drilling and facilities capital, $0.5 million of leasehold acquisition capital, and $3.0 million of other capital.
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and return on capital employed (ROCE).
Year-to-Date 2020 Financial Results
Daily equivalent production for the six-month period ended June 30, 2020 was 2,296 Mmcfe per day (100 percent natural gas). During the six-month period ended June 30, 2020, the Company drilled 36.2 net wells, completed 44.2 net wells, and placed 34.0 net wells on production.
Natural gas price realizations, including the impact of derivatives, were $1.62 per Mcf for the six-month period ended June 30, 2020, a decrease of 42 percent compared to the prior-year period. For the six-month period ended June 30, 2020, operating expenses (including interest expense) were $1.45 per Mcfe.
For the six-month period ended June 30, 2020, net income was $84.3 million, or $0.21 per share, compared to $443.8 million, or $1.05 per share, in the prior-year period. Adjusted net income (non-GAAP) was $72.0 million, or $0.18 per share, compared to $458.4 million, or $1.08 per share, in the prior-year period. EBITDAX (non-GAAP) for the six-month period ended June 30, 2020 was $325.8 million, compared to $824.7 million in the prior-year period.
For the six-month period ended June 30, 2020, net cash provided by operating activities was $341.3 million, compared to $911.9 million in the prior-year period. Discretionary cash flow (non-GAAP) for the six-month period ended June 30, 2020 was $317.7 million, compared to $807.7 million in the prior-year period. Free cash flow (non-GAAP) for the six-month period ended June 30, 2020 was ($13.5) million, compared to $381.1 million in the prior-year period. "Our modest free cash flow deficit during the first half of the year was a result of our capital program being heavily weighted towards the first half of the year, while our production volumes are more heavily weighted towards the second half of the year," noted Dinges. "We expect that our planned sequential increase in production during the third and fourth quarters, in addition to a declining capital spending profile, will allow for a return to positive free cash flow generation during the second half of the year."
Cabot incurred a total of $335.6 million of capital expenditures during the six-month period ended June 30, 2020 including $329.9 million of drilling and facilities capital, $1.3 million of leasehold acquisition capital, and $4.4 million of other capital.
Financial Position and Liquidity
As of June 30, 2020, Cabot had total debt of $1.2 billion and cash on hand of $117.2 million. The Company's net debt-to-adjusted capitalization ratio (non-GAAP) and net debt-to-trailing twelve months EBITDAX ratio (non-GAAP) were 33.7 percent and 1.2x, respectively, compared to 32.2 percent and 0.7x as of December 31, 2019. As of June 30, 2020, the Company had no debt outstanding under its credit facility.
Subsequent to the end of the second quarter, the Company repaid $87.0 million of maturities associated with its 6.51% weighted-average senior notes.
Third Quarter and Full-Year 2020 Guidance
Cabot has provided its third quarter 2020 production guidance range of 2,400 to 2,450 Mmcfe per day, resulting in the reaffirmation of the Company's full-year 2020 production guidance range of 2,350 to 2,375 Mmcfe per day based on a capital program of $575 million. "Despite our expectation for the 2020 average NYMEX price to be the lowest on record since 1995, we expect our capital program for the year to be fully funded within cash flow and to generate enough free cash flow to cover the majority of our dividend," said Dinges. "While we do not plan to provide our official 2021 guidance until early next year, based on a 2021 NYMEX price assumption of $2.75 per MMbtu, which is roughly in line with the current NYMEX futures, we can deliver similar production volumes as 2020 from a modestly lower maintenance capital program, while generating a free cash flow yield1 of approximately eight percent and a ROCE between 19 and 20 percent. Our prioritization for the deployment of our free cash flow in 2021 is funding our regular quarterly dividend, repayment of our 2021 debt maturities, and additional opportunistic returns of capital to shareholders."
For further information on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
1 Based on the Company's current market capitalization as of July 30, 2020
Conference Call Webcast
A conference call is scheduled for Friday, July 31, 2020, at 9:30 a.m. Eastern Time to discuss second quarter 2020 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, the continuing effects of the COVID-19 pandemic and the impact thereof on the Company's business, financial condition and results of operations, the availability of cash on hand and other sources of liquidity to fund our capital expenditures, the repayment of our debt maturities and our dividends, actions by, or disputes among or between, the Organization of Petroleum Exporting Countries and other producer countries, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Company's most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
2020 | 2019 | 2020 | 2019 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 202.9 | 213.8 | 417.8 | 418.6 | |||||||||||
Equivalent production (Bcfe) | 202.9 | 213.8 | 417.8 | 418.6 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,229 | 2,349 | 2,296 | 2,313 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 1.52 | $ | 2.27 | $ | 1.62 | $ | 2.80 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 1.42 | $ | 2.20 | $ | 1.58 | $ | 2.64 | |||||||
AVERAGE UNIT COSTS ($/Mcfe)(1) | |||||||||||||||
Direct operations | $ | 0.09 | $ | 0.08 | $ | 0.08 | $ | 0.09 | |||||||
Transportation and gathering | 0.67 | 0.66 | 0.67 | 0.67 | |||||||||||
Taxes other than income | 0.02 | 0.02 | 0.02 | 0.02 | |||||||||||
Exploration | 0.02 | 0.02 | 0.02 | 0.03 | |||||||||||
Depreciation, depletion and amortization | 0.47 | 0.45 | 0.47 | 0.45 | |||||||||||
General and administrative (excluding stock-based | 0.07 | 0.08 | 0.08 | 0.08 | |||||||||||
Stock-based compensation | 0.04 | 0.03 | 0.06 | 0.05 | |||||||||||
Interest expense | 0.07 | 0.07 | 0.07 | 0.06 | |||||||||||
$ | 1.44 | $ | 1.41 | $ | 1.45 | $ | 1.45 | ||||||||
WELLS DRILLED (2) | |||||||||||||||
Gross | 19 | 24 | 41 | 49 | |||||||||||
Net | 14.2 | 24.0 | 36.2 | 49.0 | |||||||||||
WELLS COMPLETED (2) | |||||||||||||||
Gross | 36 | 28 | 49 | 42 | |||||||||||
Net | 31.2 | 28.0 | 44.2 | 42.0 |
_______________________________________________________________________________ | |
(1) | Total unit cost may differ from the sum of the individual costs due to rounding. |
(2) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2020 | 2019 | 2020 | 2019 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 288,286 | $ | 470,482 | $ | 658,626 | $ | 1,103,656 | |||||||
Gain on derivative instruments | 43,974 | 63,649 | 60,036 | 71,906 | |||||||||||
Other | 88 | (14) | 143 | 236 | |||||||||||
332,348 | 534,117 | 718,805 | 1,175,798 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 17,423 | 18,093 | 34,667 | 36,427 | |||||||||||
Transportation and gathering | 135,249 | 141,689 | 278,581 | 279,022 | |||||||||||
Taxes other than income | 3,352 | 3,640 | 7,090 | 9,487 | |||||||||||
Exploration | 4,579 | 4,504 | 6,769 | 10,548 | |||||||||||
Depreciation, depletion and amortization | 94,622 | 96,147 | 194,757 | 188,405 | |||||||||||
General and administrative (excluding stock-based | 14,885 | 16,168 | 32,011 | 32,126 | |||||||||||
Stock-based compensation(1) | 8,281 | 6,721 | 24,584 | 21,853 | |||||||||||
278,391 | 286,962 | 578,459 | 577,868 | ||||||||||||
Earnings (loss) on equity method investments | — | 3,650 | (59) | 7,334 | |||||||||||
Loss on sale of assets | (241) | — | (170) | (1,500) | |||||||||||
INCOME FROM OPERATIONS | 53,716 | 250,805 | 140,117 | 603,764 | |||||||||||
Interest expense, net | 14,543 | 14,567 | 28,754 | 26,748 | |||||||||||
Other expense | 48 | 143 | 114 | 287 | |||||||||||
Income before income taxes | 39,125 | 236,095 | 111,249 | 576,729 | |||||||||||
Income tax expense | 8,751 | 55,086 | 26,965 | 132,957 | |||||||||||
NET INCOME | $ | 30,374 | $ | 181,009 | $ | 84,284 | $ | 443,772 | |||||||
Earnings per share - Basic | $ | 0.08 | $ | 0.43 | $ | 0.21 | $ | 1.05 | |||||||
Weighted-average common shares outstanding | 398,576 | 422,141 | 398,460 | 422,626 |
_______________________________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | June 30, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 463,934 | $ | 568,248 | |||
Properties and equipment, net (Successful efforts method) | 4,002,492 | 3,855,706 | |||||
Other assets | 61,444 | 63,291 | |||||
$ | 4,527,870 | $ | 4,487,245 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 206,388 | $ | 241,034 | |||
Current portion of long-term debt | 175,000 | 87,000 | |||||
Long-term debt, net (excluding current maturities) | 1,045,495 | 1,133,025 | |||||
Deferred income taxes | 754,108 | 702,104 | |||||
Other liabilities | 180,900 | 172,595 | |||||
Stockholders' equity | 2,165,979 | 2,151,487 | |||||
$ | 4,527,870 | $ | 4,487,245 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income | $ | 30,374 | $ | 181,009 | $ | 84,284 | $ | 443,772 | |||||||
Depreciation, depletion and amortization | 94,622 | 96,147 | 194,757 | 188,405 | |||||||||||
Deferred income tax expense | 8,045 | 64,645 | 52,089 | 152,647 | |||||||||||
Loss on sale of assets | 241 | — | 170 | 1,500 | |||||||||||
Exploratory dry hole cost | 2,068 | 3 | 2,011 | 16 | |||||||||||
Gain on derivative instruments | (43,974) | (63,649) | (60,036) | (71,906) | |||||||||||
Net cash received in settlement of derivative instruments | 19,423 | 15,397 | 19,423 | 68,377 | |||||||||||
Stock-based compensation and other | 7,641 | 6,584 | 23,463 | 21,058 | |||||||||||
Income charges not requiring cash | 751 | 1,746 | 1,560 | 3,880 | |||||||||||
Changes in assets and liabilities | 17,245 | 24,768 | 23,612 | 104,188 | |||||||||||
Net cash provided by operating activities | 136,436 | 326,650 | 341,333 | 911,937 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (182,481) | (225,850) | (331,183) | (421,500) | |||||||||||
Proceeds from sale of assets | 227 | — | 275 | 2,346 | |||||||||||
Investment in equity method investments | — | (3,303) | (35) | (5,131) | |||||||||||
Distribution of investment from equity method investments | — | 758 | — | 758 | |||||||||||
Proceeds from sale of equity method investments | — | — | (9,424) | — | |||||||||||
Net cash used in investing activities | (182,254) | (228,395) | (340,367) | (423,527) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | — | — | — | (7,000) | |||||||||||
Treasury stock repurchases | — | (125,260) | — | (156,638) | |||||||||||
Dividends paid | (39,858) | (38,092) | (79,675) | (67,697) | |||||||||||
Tax withholdings on vesting of stock awards | (19) | (987) | (6,332) | (10,557) | |||||||||||
Capitalized debt issuance costs | — | (7,411) | — | (7,411) | |||||||||||
Net cash used in financing activities | (39,877) | (171,750) | (86,007) | (249,303) | |||||||||||
Net (decrease) increase in cash, cash equivalents and | $ | (85,695) | $ | (73,495) | $ | (85,041) | $ | 239,107 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Adjusted Net Income is defined as net income plus gain and loss on sale of assets, gain and loss on derivative instruments, stock-based compensation expense, severance expense, interest expense related to income tax reserves and tax effect on selected items. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2020 | 2019 | 2020 | 2019 | |||||||||||
As reported - net income | $ | 30,374 | $ | 181,009 | $ | 84,284 | $ | 443,772 | |||||||
Reversal of selected items: | |||||||||||||||
Loss on sale of assets | 241 | — | 170 | 1,500 | |||||||||||
Gain on derivative instruments(1) | (24,551) | (48,252) | (40,613) | (3,529) | |||||||||||
Stock-based compensation expense | 8,281 | 6,721 | 24,584 | 21,853 | |||||||||||
Severance expense | — | 2,124 | — | 2,124 | |||||||||||
Interest expense related to income tax reserves | — | — | — | (3,052) | |||||||||||
Tax effect on selected items | 3,656 | 8,998 | 3,617 | (4,315) | |||||||||||
Adjusted net income | $ | 18,001 | $ | 150,600 | $ | 72,042 | $ | 458,353 | |||||||
As reported - earnings per share | $ | 0.08 | $ | 0.43 | $ | 0.21 | $ | 1.05 | |||||||
Per share impact of selected items | (0.03) | (0.07) | (0.03) | 0.03 | |||||||||||
Adjusted earnings per share | $ | 0.05 | $ | 0.36 | $ | 0.18 | $ | 1.08 | |||||||
Weighted-average common shares outstanding | 398,576 | 422,141 | 398,460 | 422,626 |
_______________________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as Adjusted Net Income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our profitability and the efficiency with which we have employed capital over time. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income, as defined by GAAP.
Twelve Months Ended June 30, | |||||||
(In thousands) | 2020 | 2019 | |||||
Interest expense, net | $ | 56,958 | $ | 56,563 | |||
Interest expense related to income tax reserves (1) | — | 5,453 | |||||
Tax benefit | (12,996) | (14,274) | |||||
After-tax interest expense, net (A) | 43,962 | 47,742 | |||||
As reported - net income | 321,582 | 841,153 | |||||
Adjustments to as reported - net income, net of tax | (9,128) | (38,088) | |||||
Adjusted net income (B) | 312,454 | 803,065 | |||||
Adjusted net income before interest expense, net (A + B) | $ | 356,416 | $ | 850,807 | |||
Total debt - beginning of twelve month period | $ | 1,219,555 | $ | 1,522,572 | |||
Stockholders' equity - beginning of twelve month period | 2,344,804 | 2,154,174 | |||||
Capital employed - beginning of twelve month period | 3,564,359 | 3,676,746 | |||||
Total debt - end of twelve month period | 1,220,495 | 1,219,555 | |||||
Stockholders' equity - end of twelve month period | 2,165,979 | 2,344,804 | |||||
Capital employed - end of twelve month period | 3,386,474 | 3,564,359 | |||||
Average capital employed (C) | $ | 3,475,417 | $ | 3,620,553 | |||
Return on average capital employed (ROCE) (A + B) / C | 10.3 | % | 23.5 | % |
_______________________________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, return capital to shareholders through dividends and share repurchases, and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Six Months Ended | |||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | ||||||||||||
Net cash provided by operating activities | $ | 136,436 | $ | 326,650 | $ | 341,333 | $ | 911,937 | ||||||||
Changes in assets and liabilities | (17,245) | (24,768) | (23,612) | (104,188) | ||||||||||||
Discretionary cash flow | 119,191 | 301,882 | 317,721 | 807,749 | ||||||||||||
Capital expenditures | (182,481) | (225,850) | (331,183) | (421,500) | ||||||||||||
Investment in equity method investments | — | (3,303) | (35) | (5,131) | ||||||||||||
Free cash flow | $ | (63,290) | $ | 72,729 | $ | (13,497) | $ | 381,118 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
Net income | $ | 30,374 | $ | 181,009 | $ | 84,284 | $ | 443,772 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 14,543 | 14,567 | 28,754 | 26,748 | |||||||||||
Other expense | 48 | 143 | 114 | 287 | |||||||||||
Income tax expense | 8,751 | 55,086 | 26,965 | 132,957 | |||||||||||
Depreciation, depletion and amortization | 94,622 | 96,147 | 194,757 | 188,405 | |||||||||||
Exploration | 4,579 | 4,504 | 6,769 | 10,548 | |||||||||||
Loss on sale of assets | 241 | — | 170 | 1,500 | |||||||||||
Non-cash gain on derivative instruments | (24,551) | (48,252) | (40,613) | (3,529) | |||||||||||
(Earnings) loss on equity method investments | — | (3,650) | 59 | (7,334) | |||||||||||
Equity method investment distributions | — | 4,779 | — | 9,508 | |||||||||||
Stock-based compensation | 8,281 | 6,721 | 24,584 | 21,853 | |||||||||||
EBITDAX | $ | 136,888 | $ | 311,054 | $ | 325,843 | $ | 824,715 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | June 30, | December 31, | |||||
Current portion of long-term debt | $ | 175,000 | $ | 87,000 | |||
Long-term debt, net | 1,045,495 | 1,133,025 | |||||
Total debt | $ | 1,220,495 | $ | 1,220,025 | |||
Stockholders' equity | 2,165,979 | 2,151,487 | |||||
Total capitalization | $ | 3,386,474 | $ | 3,371,512 | |||
Total debt | $ | 1,220,495 | $ | 1,220,025 | |||
Less: Cash and cash equivalents | (117,164) | (200,227) | |||||
Net debt | $ | 1,103,331 | $ | 1,019,798 | |||
Net debt | $ | 1,103,331 | $ | 1,019,798 | |||
Stockholders' equity | 2,165,979 | 2,151,487 | |||||
Total adjusted capitalization | $ | 3,269,310 | $ | 3,171,285 | |||
Total debt to total capitalization ratio | 36.0 | % | 36.2 | % | |||
Less: Impact of cash and cash equivalents | 2.3 | % | 4.0 | % | |||
Net debt to adjusted capitalization ratio | 33.7 | % | 32.2 | % |
Capital Expenditures | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands) | 2020 | 2019 | 2020 | 2019 | |||||||||||
Cash paid for capital expenditures | $ | 182,481 | $ | 225,850 | $ | 331,183 | $ | 421,500 | |||||||
Change in accrued capital costs | (5,149) | (5,466) | 6,397 | 3,168 | |||||||||||
Exploratory dry hole cost | (2,068) | (3) | (2,011) | (16) | |||||||||||
Capital expenditures | $ | 175,264 | $ | 220,381 | $ | 335,569 | $ | 424,652 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-second-quarter-2020-results-301103518.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 29, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of ten cents ($0.10) per share on the Company's common stock. The dividend will be paid on August 27, 2020 to all shareholders of record as of the close of business on August 13, 2020.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-301102534.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 2, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it plans to release its financial and operating results on Thursday, July 30, 2020, after market closes. The Company will host its second quarter 2020 earnings conference call on Friday, July 31, 2020 at 9:30 a.m. Eastern Time.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-second-quarter-2020-earnings-release-and-conference-call-301087381.html
SOURCE Cabot Oil & Gas Corporation
NEW YORK, June 24, 2020 /PRNewswire/ -- Pomerantz LLP is investigating claims on behalf of investors of Cabot Oil & Gas Corporation ("Cabot Oil" or the "Company") (NYSE: COG). Such investors are advised to contact Robert S. Willoughby at rswilloughby@pomlaw.com or 888-476-6529, ext. 7980.
The investigation concerns whether Cabot Oil and certain of its officers and/or directors have engaged in securities fraud or other unlawful business practices.
[Click here for information about joining the class action]
On June 15, 2020, following a grand jury investigation, the Pennsylvania attorney general's office charged Cabot Oil with 15 criminal counts arising from its failure to fix faulty gas wells, thereby polluting Pennsylvania's water supplies through stray gas migration.
On this news, Cabot Oil's stock price fell $0.67 per share, or 3.34%, to close at $19.40 per share on June 15, 2020.
The Pomerantz Firm, with offices in New York, Chicago, Los Angeles, and Paris is acknowledged as one of the premier firms in the areas of corporate, securities, and antitrust class litigation. Founded by the late Abraham L. Pomerantz, known as the dean of the class action bar, the Pomerantz Firm pioneered the field of securities class actions. Today, more than 80 years later, the Pomerantz Firm continues in the tradition he established, fighting for the rights of the victims of securities fraud, breaches of fiduciary duty, and corporate misconduct. The Firm has recovered numerous multimillion-dollar damages awards on behalf of class members. See www.pomerantzlaw.com.
CONTACT:
Robert S. Willoughby
Pomerantz LLP
rswilloughby@pomlaw.com
888-476-6529 ext. 7980
View original content:http://www.prnewswire.com/news-releases/shareholder-alert-pomerantz-law-firm-investigates-claims-on-behalf-of-investors-of-cabot-oil--gas-corporation---cog-301083270.html
SOURCE Pomerantz LLP
HOUSTON, April 30, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of ten cents ($0.10) per share on the Company's common stock. The dividend will be paid on May 28, 2020 to all shareholders of record as of the close of business on May 14, 2020.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-301050496.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 30, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the first quarter of 2020.
"During these unprecedented times, I am reminded of the strength of our company and the resiliency of our business model, which are a result of our low cost structure, our strong balance sheet, and the tireless hard work of our employees," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "We have implemented preventative measures intended to minimize unnecessary risk of exposure and prevent infection among our employees and the communities in which we operate. Our operations team—in conjunction with our service and midstream providers—has continued to execute on our plan with little disruption. While natural gas prices are expected to remain challenged in the near-term as we manage through an oversupplied market exiting the winter heating season and the unexpected loss in demand resulting from COVID-19, we expect a much healthier supply and demand balance for natural gas later this year and in 2021. Our improved outlook for the natural gas markets is primarily driven by our expectation for significant declines in natural gas supply in 2020 and 2021 due to a continued reduction in natural gas-directed drilling and completion activity and less associated gas production from reduced operating activity in oil basins driven by the COVID-19 pandemic and recent production disagreements among members of OPEC+ and other producer countries."
First Quarter 2020 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and ROCE.
First Quarter 2020 Financial Results
First quarter 2020 daily production was 2,363 Mmcfe per day (100 percent natural gas), representing a four percent increase relative to the first quarter of 2019.
First quarter 2020 net income was $53.9 million, or $0.14 per share, compared to $262.8 million, or $0.62 per share, in the prior-year period. First quarter 2020 adjusted net income (non-GAAP) was $54.0 million, or $0.14 per share, compared to $307.8 million, or $0.73 per share, in the prior-year period. First quarter 2020 EBITDAX (non-GAAP) was $189.0 million, compared to $513.7 million in the prior-year period.
First quarter 2020 net cash provided by operating activities was $204.9 million, compared to $585.3 million in the prior-year period. First quarter 2020 discretionary cash flow (non-GAAP) was $198.5 million, compared to $505.9 million in the prior-year period. First quarter 2020 free cash flow (non-GAAP) was $49.8 million, compared to $308.4 million in the prior-year period.
First quarter 2020 natural gas price realizations, including the impact of derivatives, were $1.72 per thousand cubic feet (Mcf), a decrease of 49 percent compared to the prior-year period. First quarter 2020 natural gas price realizations represented a $0.23 discount to NYMEX settlement prices compared to a $0.06 discount in the prior-year period. First quarter 2020 operating expenses (including interest expense) decreased to $1.46 per thousand cubic feet equivalent (Mcfe), a one percent improvement compared to the prior-year period.
Cabot incurred a total of $160.3 million of capital expenditures in the first quarter of 2020 including $158.0 million of drilling and facilities capital, $0.9 million of leasehold acquisition capital, and $1.4 million of other capital. See the supplemental table at the end of this press release reconciling the capital expenditures during the first quarter of 2020.
Financial Position and Liquidity
As of March 31, 2020, Cabot had total debt of $1.2 billion and cash on hand of $202.8 million. The Company's net debt-to-adjusted capitalization ratio (non-GAAP) and net debt-to-trailing twelve months EBITDAX ratio (non-GAAP) were 31.9 percent and 0.9x, respectively, compared to 32.2 percent and 0.7x as of December 31, 2019.
On April 23, 2020, the Company's lender group unanimously reaffirmed the $3.2 billion borrowing base under its revolving credit facility. Aggregate bank commitments under the credit facility remain at $1.5 billion. The Company currently has no debt outstanding under its credit facility, resulting in approximately $1.7 billion of liquidity.
"Despite the lowest average quarterly NYMEX settlement price since the first quarter of 1999, Cabot was still able to deliver positive corporate returns and generate positive free cash flow while fully funding our dividend and maintaining an ironclad balance sheet," added Dinges. "I am proud of our team and these results given the unprecedented environment we are operating in today."
Second Quarter and Full-Year 2020 Guidance
Cabot has provided its second quarter 2020 production guidance range of 2,175 to 2,225 Mmcfe per day. As the Company previously disclosed, this sequential production decline in the second quarter is primarily driven by a lighter turn-in-line schedule during the first four and a half months of the year with only thirteen wells expected to be placed on production between the beginning of the year and mid-May. This is primarily a result of longer cycle times for larger pads with longer laterals during the first and second quarters. Additionally, the Company is forecasting modest price-related curtailments during the natural gas shoulder season. The Company's second quarter production guidance range also reflects the impact of unplanned downtime related to remedial work on one well on a large pad that resulted in the deferral of over 230 completed stages from the first quarter to the second quarter, which led to lower capital spending levels in the first quarter. Based on the current turn-in-line schedule for the year, approximately two-thirds of the Company's wells are expected to be placed on production between mid-May and late August, resulting in a significant sequential production increase in the third quarter of 2020.
Cabot has updated its full-year production guidance from 2,400 Mmcfe per day to a range of 2,350 to 2,375 Mmcfe per day to reflect the previously mentioned operational changes and has reaffirmed its capital program of $575 million. "The midpoint of our updated production guidance range implies flat production levels year-over-year, with fourth quarter 2020 exit volumes expected to be flat to the fourth quarter of 2019," said Dinges. Based on the current NYMEX futures curve, this plan is currently expected to generate enough free cash flow to fully fund the Company's dividend in 2020. For further information on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
"As it relates to our outlook for 2021, we are extremely encouraged by the increase in the NYMEX natural gas futures for 2021 from a low of $2.28 per Mmbtu in early March to approximately $2.75 per Mmbtu today," commented Dinges. "Under a maintenance capital program in 2021, every $0.10 improvement in annual NYMEX price is expected to result in approximately $55 million of incremental free cash flow, highlighting our belief in our ability to deliver a significant expansion in free cash flow next year. We will continue to assess the natural gas market dynamics, including the impact of COVID-19 and lower crude oil prices on the natural gas supply and demand outlook, before formalizing our plans for 2021; however, we are optimistic that our improving outlook for free cash flow, return on capital employed, and return of capital to shareholders will further differentiate Cabot through these challenging times."
Conference Call Webcast
A conference call is scheduled for Friday, May 1, 2020, at 9:30 a.m. Eastern Time to discuss first quarter 2020 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, the effects of the COVID-19 pandemic and the impact thereof on the Company's business, financial condition and results of operations, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and Form 10-Q and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||
Three Months Ended | |||||||
2020 | 2019 | ||||||
PRODUCTION VOLUMES | |||||||
Natural gas (Bcf) | 215.0 | 204.8 | |||||
Equivalent production (Bcfe) | 215.0 | 204.8 | |||||
Daily equivalent production (Mmcfe/day) | 2,363 | 2,276 | |||||
AVERAGE SALES PRICE | |||||||
Natural gas, including hedges ($/Mcf) | $ | 1.72 | $ | 3.35 | |||
Natural gas, excluding hedges ($/Mcf) | $ | 1.72 | $ | 3.09 | |||
AVERAGE UNIT COSTS ($/Mcfe)(1) | |||||||
Direct operations | $ | 0.08 | $ | 0.09 | |||
Transportation and gathering | 0.67 | 0.67 | |||||
Taxes other than income | 0.02 | 0.03 | |||||
Exploration | 0.01 | 0.03 | |||||
Depreciation, depletion and amortization | 0.47 | 0.45 | |||||
General and administrative (excluding stock-based compensation) | 0.08 | 0.08 | |||||
Stock-based compensation | 0.08 | 0.07 | |||||
Interest expense | 0.07 | 0.06 | |||||
$ | 1.46 | $ | 1.48 | ||||
WELLS DRILLED (2) | |||||||
Gross | 22 | 25 | |||||
Net | 22.0 | 25.0 | |||||
WELLS COMPLETED (2) | |||||||
Gross | 13 | 14 | |||||
Net | 13.0 | 14.0 |
_______________________________________________________________________________ | |
(1) | Total unit cost may differ from the sum of the individual costs due to rounding. |
(2) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands, except per share amounts) | 2020 | 2019 | |||||
OPERATING REVENUES | |||||||
Natural gas | $ | 370,340 | $ | 633,174 | |||
Gain on derivative instruments | 16,062 | 8,257 | |||||
Other | 55 | 250 | |||||
386,457 | 641,681 | ||||||
OPERATING EXPENSES | |||||||
Direct operations | 17,244 | 18,334 | |||||
Transportation and gathering | 143,332 | 137,333 | |||||
Taxes other than income | 3,738 | 5,847 | |||||
Exploration | 2,190 | 6,044 | |||||
Depreciation, depletion and amortization | 100,135 | 92,258 | |||||
General and administrative (excluding stock-based compensation) | 17,126 | 15,958 | |||||
Stock-based compensation(1) | 16,303 | 15,132 | |||||
300,068 | 290,906 | ||||||
Earnings (loss) on equity method investments | (59) | 3,684 | |||||
Gain (loss) on sale of assets | 71 | (1,500) | |||||
INCOME FROM OPERATIONS | 86,401 | 352,959 | |||||
Interest expense, net | 14,211 | 12,181 | |||||
Other expense | 66 | 144 | |||||
Income before income taxes | 72,124 | 340,634 | |||||
Income tax expense | 18,214 | 77,871 | |||||
NET INCOME | $ | 53,910 | $ | 262,763 | |||
Earnings per share - Basic | $ | 0.14 | $ | 0.62 | |||
Weighted-average common shares outstanding | 398,343 | 423,116 |
_______________________________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | March 31, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 541,789 | $ | 568,248 | |||
Properties and equipment, net (Successful efforts method) | 3,920,497 | 3,855,706 | |||||
Other assets | 59,889 | 63,291 | |||||
$ | 4,522,175 | $ | 4,487,245 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 212,177 | $ | 241,034 | |||
Current portion of long-term debt | 175,000 | 87,000 | |||||
Long-term debt, net (excluding current maturities) | 1,045,260 | 1,133,025 | |||||
Deferred income taxes | 746,108 | 702,104 | |||||
Other liabilities | 175,235 | 172,595 | |||||
Stockholders' equity | 2,168,395 | 2,151,487 | |||||
$ | 4,522,175 | $ | 4,487,245 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands) | 2020 | 2019 | |||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||
Net income | $ | 53,910 | $ | 262,763 | |||
Depreciation, depletion and amortization | 100,135 | 92,258 | |||||
Deferred income tax expense | 44,044 | 88,002 | |||||
(Gain) loss on sale of assets | (71) | 1,500 | |||||
Gain on derivative instruments | (16,062) | (8,257) | |||||
Net cash received in settlement of derivative instruments | — | 52,980 | |||||
Stock-based compensation and other | 15,765 | 14,487 | |||||
Income charges not requiring cash | 809 | 2,134 | |||||
Changes in assets and liabilities | 6,367 | 79,420 | |||||
Net cash provided by operating activities | 204,897 | 585,287 | |||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||
Capital expenditures | (148,702) | (195,650) | |||||
Proceeds from sale of assets | 48 | 2,346 | |||||
Investment in equity method investments | (35) | (1,828) | |||||
Proceeds from sale of equity method investments | (9,424) | — | |||||
Net cash used in investing activities | (158,113) | (195,132) | |||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||
Net borrowings (repayments) of debt | — | (7,000) | |||||
Treasury stock repurchases | — | (31,378) | |||||
Dividends paid | (39,817) | (29,605) | |||||
Tax withholdings on vesting of stock awards | (6,313) | (9,570) | |||||
Net cash used in financing activities | (46,130) | (77,553) | |||||
Net increase in cash, cash equivalents and restricted cash | $ | 654 | $ | 312,602 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Adjusted Net Income is defined as net income plus gain and loss on sale of assets, gain and loss on derivative instruments, stock-based compensation expense, interest expense related to income tax reserves and tax effect on selected items. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Three Months Ended | |||||||
(In thousands, except per share amounts) | 2020 | 2019 | |||||
As reported - net income | $ | 53,910 | $ | 262,763 | |||
Reversal of selected items: | |||||||
(Gain) loss on sale of assets | (71) | 1,500 | |||||
(Gain) loss on derivative instruments(1) | (16,062) | 44,723 | |||||
Stock-based compensation expense | 16,303 | 15,132 | |||||
Interest expense related to income tax reserves | — | (3,052) | |||||
Tax effect on selected items | (39) | (13,313) | |||||
Adjusted net income | $ | 54,041 | $ | 307,753 | |||
As reported - earnings per share | $ | 0.14 | $ | 0.62 | |||
Per share impact of selected items | — | 0.11 | |||||
Adjusted earnings per share | $ | 0.14 | $ | 0.73 | |||
Weighted-average common shares outstanding | 398,343 | 423,116 |
_______________________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as Adjusted Net Income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our profitability and the efficiency with which we have employed capital over time. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
Twelve Months Ended March 31, | |||||||
(In thousands) | 2020 | 2019 | |||||
Interest expense, net | $ | 56,982 | $ | 65,324 | |||
Interest expense related to income tax reserves (1) | — | (64) | |||||
Tax benefit | (13,005) | (15,140) | |||||
After-tax interest expense, net (A) | 43,977 | 50,120 | |||||
As reported - net income | 472,217 | 702,575 | |||||
Adjustments to as reported - net income, net of tax | (27,164) | 7,753 | |||||
Adjusted net income (B) | 445,053 | 710,328 | |||||
Adjusted net income before interest expense, net (A + B) | $ | 489,030 | $ | 760,448 | |||
Total debt - beginning of twelve month period | $ | 1,219,338 | $ | 1,522,231 | |||
Stockholders' equity - beginning of twelve month period | 2,320,939 | 2,406,516 | |||||
Capital employed - beginning of twelve month period | 3,540,277 | 3,928,747 | |||||
Total debt - end of twelve month period | 1,220,260 | 1,219,338 | |||||
Stockholders' equity - end of twelve month period | 2,168,395 | 2,320,939 | |||||
Capital employed - end of twelve month period | 3,388,655 | 3,540,277 | |||||
Average capital employed (C) | $ | 3,464,466 | $ | 3,734,512 | |||
Return on average capital employed (ROCE) (A + B) / C | 14.1 | % | 20.4 | % |
_______________________________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, return capital to shareholders through dividends and share repurchases, and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Three Months Ended | |||||||
(In thousands) | 2020 | 2019 | |||||
Net cash provided by operating activities | $ | 204,897 | $ | 585,287 | |||
Changes in assets and liabilities | (6,367) | (79,420) | |||||
Discretionary cash flow | 198,530 | 505,867 | |||||
Capital expenditures | (148,702) | (195,650) | |||||
Investment in equity method investments | (35) | (1,828) | |||||
Free cash flow | $ | 49,793 | $ | 308,389 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Three Months Ended | |||||||
(In thousands) | 2020 | 2019 | |||||
Net income | $ | 53,910 | $ | 262,763 | |||
Plus (less): | |||||||
Interest expense, net | 14,211 | 12,181 | |||||
Other expense | 66 | 144 | |||||
Income tax expense | 18,214 | 77,871 | |||||
Depreciation, depletion and amortization | 100,135 | 92,258 | |||||
Exploration | 2,190 | 6,044 | |||||
(Gain) loss on sale of assets | (71) | 1,500 | |||||
Non-cash (gain) loss on derivative instruments | (16,062) | 44,723 | |||||
(Earnings) loss on equity method investments | 59 | (3,684) | |||||
Equity method investment distributions | — | 4,729 | |||||
Stock-based compensation | 16,303 | 15,132 | |||||
EBITDAX | $ | 188,955 | $ | 513,661 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | March 31, | December 31, | |||||
Current portion of long-term debt | $ | 175,000 | $ | 87,000 | |||
Long-term debt, net | 1,045,260 | 1,133,025 | |||||
Total debt | $ | 1,220,260 | $ | 1,220,025 | |||
Stockholders' equity | 2,168,395 | 2,151,487 | |||||
Total capitalization | $ | 3,388,655 | $ | 3,371,512 | |||
Total debt | $ | 1,220,260 | $ | 1,220,025 | |||
Less: Cash and cash equivalents | (202,842) | (200,227) | |||||
Net debt | $ | 1,017,418 | $ | 1,019,798 | |||
Net debt | $ | 1,017,418 | $ | 1,019,798 | |||
Stockholders' equity | 2,168,395 | 2,151,487 | |||||
Total adjusted capitalization | $ | 3,185,813 | $ | 3,171,285 | |||
Total debt to total capitalization ratio | 36.0 | % | 36.2 | % | |||
Less: Impact of cash and cash equivalents | 4.1 | % | 4.0 | % | |||
Net debt to adjusted capitalization ratio | 31.9 | % | 32.2 | % |
Capital Expenditures | |||||||
Three Months Ended | |||||||
(In thousands) | 2020 | 2019 | |||||
Cash paid for capital expenditures | $ | 148,702 | $ | 195,650 | |||
Change in accrued capital costs | 11,546 | 8,634 | |||||
Exploratory dry hole cost | 57 | (13) | |||||
Capital expenditures | $ | 160,305 | $ | 204,271 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-first-quarter-2020-results-announces-reaffirmation-of-borrowing-base-301050453.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 9, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it plans to release its financial and operating results on Thursday, April 30, 2020, after market closes. The Company will host its first quarter 2020 earnings conference call on Friday, May 1, 2020 at 9:30 a.m. Eastern Time.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-first-quarter-2020-earnings-release-and-conference-call-301038439.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 20, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the fourth quarter and full-year 2019.
"Our 2019 results highlight the strength of our company, which was demonstrated by the generation of record levels for net income, operating cash flow, free cash flow, production, proved reserves and operating expenses," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "While we continue to manage through headwinds from lower natural gas prices, our low cost structure and low leverage position will allow us to continue to generate positive free cash flow and economic corporate returns, maintain our financial strength, and return capital to shareholders during these challenging times for the natural gas markets."
Full-Year 2019 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, ROCE, pre-tax present value of future net cash flows (pre-tax PV-10) and F&D costs.
Fourth Quarter 2019 Financial Results
Fourth quarter 2019 daily production was 2,457 Mmcfe per day (100 percent natural gas), exceeding the high-end of the Company's guidance range and representing a 10 percent increase relative to the fourth quarter of 2018.
Fourth quarter 2019 net income was $146.9 million, or $0.36 per share, compared to $275.0 million, or $0.64 per share, in the prior-year period. Fourth quarter 2019 adjusted net income (non-GAAP) was $120.8 million, or $0.30 per share, compared to $235.8 million, or $0.55 per share, in the prior-year period. Fourth quarter 2019 EBITDAX (non-GAAP) was $300.3 million, compared to $464.4 million in the prior-year period.
Fourth quarter 2019 net cash provided by operating activities was $263.0 million, compared to $316.1 million in the prior-year period. Fourth quarter 2019 discretionary cash flow (non-GAAP) was $277.5 million, compared to $492.8 million in the prior-year period. Fourth quarter 2019 free cash flow (non-GAAP) was $109.5 million, compared to $241.4 million in the prior-year period.
Fourth quarter 2019 natural gas price realizations, including the impact of derivatives, were $2.15 per thousand cubic feet (Mcf), a decrease of 31 percent compared to the prior-year period. Excluding the impact of derivatives, fourth quarter 2019 natural gas price realizations were $2.05 per Mcf, representing a $0.45 discount to NYMEX settlement prices compared to a $0.42 discount in the prior-year period.
Fourth quarter 2019 operating expenses (including interest expense) decreased to $1.43 per Mcfe, a 24 percent improvement compared to the prior-year period. All operating expenses per unit decreased relative to the prior-year period except for direct operations, which increased slightly primarily due to higher workover expense compared to the prior-year period.
Cabot incurred a total of $161.1 million of capital expenditures in the fourth quarter of 2019 including $155.5 million of drilling and facilities capital, $0.8 million of leasehold acquisition capital, and $4.8 million of other capital. Additionally, the Company contributed $0.4 million to its recently divested equity method pipeline investments. See the supplemental table at the end of this press release reconciling the capital expenditures during the fourth quarter of 2019.
Full-Year 2019 Financial Results
Full-year 2019 daily production was 2,371 Mmcfe per day (100 percent natural gas), representing an 18 percent increase relative to the prior-year period.
Full-year 2019 net income was $681.1 million, or $1.64 per share, compared to $557.0 million, or $1.25 per share, for the prior-year period. Adjusted net income (non-GAAP) for the full-year 2019 was $698.8 million, or $1.68 per share, compared to $531.2 million, or $1.19 per share, for the prior-year period. Full-year 2019 EBITDAX (non-GAAP) was $1.4 billion, compared to $1.3 billion for the prior-year period.
For the full-year 2019, net cash provided by operating activities was $1.4 billion, compared to $1.1 billion for the prior-year period. Full-year 2019 discretionary cash flow (non-GAAP) was $1.4 billion, compared to $1.3 billion for the prior-year period. Full-year 2019 free cash flow (non-GAAP) was $563.1 million, compared to $296.6 million for the prior-year period. Full-year 2019 ROCE (non-GAAP) improved to 22.2 percent, compared to 15.9 percent for the prior-year period.
Full-year 2019 natural gas price realizations, including the impact of derivatives, were $2.45 per Mcf, a decrease of four percent compared to the prior-year period.
Full-year 2019 operating expenses (including interest expense) decreased to $1.44 per Mcfe, an 18 percent improvement compared to the prior-year period. All operating expenses per unit decreased relative to the prior-year period.
Cabot incurred a total of $783.3 million of capital expenditures in 2019 including $761.5 million of drilling and facilities capital, $6.1 million of leasehold acquisition capital, and $15.7 million of other capital. Additionally, the Company contributed $9.3 million to its recently divested equity method pipeline investments in 2019. See the supplemental table at the end of this press release reconciling the capital expenditures for the year.
Return of Capital
Cabot returned $665.4 million of capital to shareholders through dividends and share repurchases in 2019, representing 118 percent of the Company's free cash flow. During the year, Cabot increased its quarterly dividend per share by 43 percent and repurchased 25.5 million shares. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 14 percent to 398.6 million shares. The Company currently has 11.0 million remaining shares authorized under its share repurchase program (or approximately three percent of its current shares outstanding). Cabot continues to target a minimum return of capital of at least 50 percent of free cash flow annually.
Financial Position and Liquidity
As of December 31, 2019, Cabot had total debt of $1.2 billion and cash on hand of $200.2 million. The Company's net debt-to-adjusted capitalization ratio and net debt-to-trailing twelve months EBITDAX ratio were 32.2 percent and 0.7x, respectively, compared to 37.0 percent and 1.0x as of December 31, 2018. The Company currently has no debt outstanding under its credit facility, resulting in approximately $1.7 billion of liquidity.
Upper Marcellus Operations Update
During 2018 and 2019, Cabot placed 25 Upper Marcellus wells on production. Excluding four wells that were located on a pad where the Company had an underperforming lateral placement pilot test, the average estimated ultimate recovery (EUR) per thousand lateral feet was 2.7 Bcf. "We believe the results from our recent Upper Marcellus wells highlight the Upper Marcellus as a distinct, economic interval that exceeds the average well productivity across the basin," stated Dinges. "Our prolific acreage position in northeast Pennsylvania provides us with over two decades of remaining drilling locations, including nine years of remaining Lower Marcellus inventory." The Company plans to test an additional five Upper Marcellus wells in 2020 to further optimize lateral placement and completion design.
Year-End 2019 Proved Reserves
Cabot reported year-end proved reserves of 12.9 Tcfe, an increase of 11 percent over year-end 2018. The table below reconciles the components driving the 2019 reserve increase:
Proved Reserves Reconciliation (in Bcfe) | |||
Balance at December 31, 2018 | 11,605 | ||
Revisions of prior estimates | 47 | ||
Extensions, discoveries and other additions | 2,116 | ||
Production | (865) | ||
Balance at December 31, 2019 | 12,903 |
As of December 31, 2019, 100 percent of Cabot's year-end proved reserves were natural gas and were located in the Marcellus Shale. Approximately 62 percent of the year-end proved reserves were classified as proved developed and 38 percent were classified as proved undeveloped (PUD), including six percent of drilled and uncompleted PUDs
Total costs incurred during 2019 were $787.7 million, which included $761.3 million for development costs, $20.3 million for exploration costs, and $6.1 million for lease acquisition costs. All-sources F&D costs (non-GAAP) were $0.36 per Mcfe, while drill-bit F&D costs (non-GAAP) were $0.37 per Mcfe in 2019.
The SEC price used for reporting Cabot's year-end 2019 proved reserves, which has been adjusted for basis and quality differentials, was $2.35 per Mcf, a nine percent year-over-year decrease. Assuming the SEC price, the pre-tax PV–10 (non-GAAP) of the year-end 2019 proved reserves was $7.5 billion, an eight percent decrease compared to $8.1 billion at year-end 2018.
First Quarter and Full-Year 2020 Guidance
Cabot has provided its first quarter 2020 production guidance range of 2,350 to 2,400 Mmcfe per day, representing a three percent sequential decline at the midpoint of the range relative to the fourth quarter of 2019. Based on the timing of wells being placed on production throughout the year, the Company anticipates an additional sequential decline in the second quarter of 2020 before increasing volumes in the second half of the year.
Cabot has also reaffirmed its recently announced plan to deliver an average net production rate of approximately 2,400 Mmcfe per day in 2020 from a capital program of $575 million. Based on the current NYMEX futures curve, this plan is expected to generate enough free cash flow to cover the Company's dividend while also providing a modest amount of excess free cash flow for further return of capital to shareholders or debt repayment. At a $2.25 average NYMEX price, the plan is expected to deliver between $275 and $300 million of free cash flow and generate a return on capital employed between 11 and 12 percent. The Company continues to analyze the outlook for the natural gas markets in 2020 and beyond and is prepared to reduce capital spending further if market conditions warrant it.
Conference Call Webcast
A conference call is scheduled for Friday, February 21, 2020, at 9:30 a.m. Eastern Time to discuss fourth quarter and full-year 2019 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 226.1 | 206.3 | 865.3 | 729.9 | |||||||||||
Crude oil and condensate (Mbbl) | — | — | — | 754.0 | |||||||||||
Natural gas liquids (NGLs) (Mbbl) | — | — | — | 75.1 | |||||||||||
Equivalent production (Bcfe) | 226.1 | 206.3 | 865.3 | 735.0 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,457 | 2,243 | 2,371 | 2,014 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 2.15 | $ | 3.11 | $ | 2.45 | $ | 2.54 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 2.05 | $ | 3.22 | $ | 2.29 | $ | 2.58 | |||||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 63.68 | |||||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 64.68 | |||||||
NGL ($/Bbl) | $ | — | $ | — | $ | — | $ | 21.51 | |||||||
AVERAGE UNIT COSTS ($/Mcfe)(1) | |||||||||||||||
Direct operations | $ | 0.09 | $ | 0.08 | $ | 0.09 | $ | 0.09 | |||||||
Transportation and gathering | 0.66 | 0.68 | 0.66 | 0.68 | |||||||||||
Taxes other than income | 0.01 | 0.03 | 0.02 | 0.03 | |||||||||||
Exploration | 0.02 | 0.22 | 0.02 | 0.15 | |||||||||||
Depreciation, depletion and amortization | 0.47 | 0.63 | 0.47 | 0.57 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.07 | 0.07 | 0.07 | 0.09 | |||||||||||
Stock-based compensation | 0.03 | 0.08 | 0.04 | 0.05 | |||||||||||
Interest expense | 0.06 | 0.08 | 0.06 | 0.10 | |||||||||||
$ | 1.43 | $ | 1.87 | $ | 1.44 | $ | 1.76 | ||||||||
WELLS DRILLED(2) | |||||||||||||||
Gross | 25 | 37 | 96 | 97 | |||||||||||
Net | 23.0 | 35.1 | 94.0 | 95.1 | |||||||||||
WELLS COMPLETED(2) | |||||||||||||||
Gross | 28 | 33 | 99 | 94 | |||||||||||
Net | 26.0 | 32.0 | 97.0 | 93.0 |
_______________________________________________________________________________ | |
(1) | Total unit cost may differ from the sum of the individual costs due to rounding. |
(2) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 463,451 | $ | 663,547 | $ | 1,985,240 | $ | 1,881,150 | |||||||
Crude oil and condensate | — | — | — | 48,722 | |||||||||||
Gain (loss) on derivative instruments | (2,158) | 46,060 | 80,808 | 44,432 | |||||||||||
Brokered natural gas | — | 6,155 | — | 209,530 | |||||||||||
Other | 75 | 539 | 229 | 4,314 | |||||||||||
461,368 | 716,301 | 2,066,277 | 2,188,148 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 21,350 | 16,889 | 76,958 | 69,646 | |||||||||||
Transportation and gathering | 149,974 | 140,883 | 574,677 | 496,731 | |||||||||||
Brokered natural gas | — | 5,761 | — | 184,198 | |||||||||||
Taxes other than income | 2,959 | 7,208 | 17,053 | 22,642 | |||||||||||
Exploration | 5,241 | 45,654 | 20,270 | 113,820 | |||||||||||
Depreciation, depletion and amortization | 106,439 | 129,269 | 405,733 | 417,479 | |||||||||||
General and administrative (excluding stock-based compensation) | 15,692 | 15,113 | 64,090 | 63,494 | |||||||||||
Stock-based compensation(1) | 6,808 | 15,516 | 30,780 | 33,147 | |||||||||||
308,463 | 376,293 | 1,189,561 | 1,401,157 | ||||||||||||
Earnings on equity method investments | 69,302 | 2,146 | 80,496 | 1,137 | |||||||||||
Gain (loss) on sale of assets | 2 | (1,477) | (1,462) | (16,327) | |||||||||||
INCOME FROM OPERATIONS | 222,209 | 340,677 | 955,750 | 771,801 | |||||||||||
Interest expense, net | 14,650 | 15,624 | 54,952 | 73,201 | |||||||||||
Other expense | 144 | 116 | 574 | 463 | |||||||||||
Income before income taxes | 207,415 | 324,937 | 900,224 | 698,137 | |||||||||||
Income tax expense | 60,475 | 49,893 | 219,154 | 141,094 | |||||||||||
NET INCOME | $ | 146,940 | $ | 275,044 | $ | 681,070 | $ | 557,043 | |||||||
Earnings per share - Basic | $ | 0.36 | $ | 0.64 | $ | 1.64 | $ | 1.25 | |||||||
Weighted-average common shares outstanding | 404,581 | 430,978 | 415,514 | 445,538 |
_______________________________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | December 31, 2019 | December 31, 2018 | |||||
ASSETS | |||||||
Current assets | $ | 568,248 | $ | 544,545 | |||
Properties and equipment, net (Successful efforts method) | 3,855,706 | 3,463,606 | |||||
Other assets | 63,291 | 190,678 | |||||
$ | 4,487,245 | $ | 4,198,829 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | 241,034 | $ | 287,264 | ||||
Current portion of long-term debt | 87,000 | — | |||||
Long-term debt, net (excluding current maturities) | 1,133,025 | 1,226,104 | |||||
Deferred income taxes | 702,104 | 458,597 | |||||
Other liabilities | 172,595 | 138,705 | |||||
Stockholders' equity | 2,151,487 | 2,088,159 | |||||
$ | 4,487,245 | $ | 4,198,829 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income | $ | 146,940 | $ | 275,044 | $ | 681,070 | $ | 557,043 | |||||||
Deferred income tax expense | 55,421 | 97,804 | 244,418 | 229,603 | |||||||||||
(Gain) loss on sale of assets | (2) | 1,477 | 1,462 | 16,327 | |||||||||||
Exploratory dry hole cost | 2,220 | 41,316 | 2,236 | 97,741 | |||||||||||
(Gain) loss on derivative instruments | 2,158 | (46,060) | (80,808) | (44,432) | |||||||||||
Net cash received (paid) in settlement of derivative instruments | 23,519 | (21,277) | 138,450 | (41,631) | |||||||||||
Distribution of earnings from equity method investments | 3,115 | 1,296 | 15,725 | 1,296 | |||||||||||
Income charges not requiring cash | 44,173 | 143,204 | 358,212 | 452,416 | |||||||||||
Changes in assets and liabilities | (14,564) | (176,753) | 85,026 | (163,460) | |||||||||||
Net cash provided by operating activities | 262,980 | 316,051 | 1,445,791 | 1,104,903 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (167,672) | (246,967) | (788,368) | (894,470) | |||||||||||
Proceeds from sale of assets | 199 | 2,825 | 2,600 | 678,350 | |||||||||||
Investment in equity method investments | (361) | (4,397) | (9,338) | (77,263) | |||||||||||
Distribution of investment from equity method investments | 72 | — | 1,728 | — | |||||||||||
Proceeds from sale of equity method investments | 249,463 | — | 249,463 | — | |||||||||||
Net cash provided by (used in) investing activities | 81,701 | (248,539) | (543,915) | (293,383) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | — | (60,000) | (7,000) | (297,000) | |||||||||||
Treasury stock repurchases | (172,417) | (291,036) | (519,863) | (872,761) | |||||||||||
Dividends paid | (40,793) | (30,184) | (145,515) | (111,369) | |||||||||||
Tax withholding on vesting of stock awards | (3) | (82) | (10,590) | (8,150) | |||||||||||
Capitalized debt issuance costs | (1) | — | (7,412) | — | |||||||||||
Net cash used in financing activities | (213,214) | (381,302) | (690,380) | (1,289,280) | |||||||||||
Net increase (decrease) in cash, cash equivalents and restricted cash | $ | 131,467 | $ | (313,790) | $ | 211,496 | $ | (477,760) |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results and results of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Adjusted Net Income is defined as net income plus gain and loss on sale of assets, gain and loss on derivative instruments, gain on sale of equity method investment, stock-based compensation expense, severance expense, interest expense related to income tax reserves and tax effect on selected items. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
As reported - net income | $ | 146,940 | $ | 275,044 | $ | 681,070 | $ | 557,043 | |||||||
Reversal of selected items: | |||||||||||||||
(Gain) loss on sale of assets | (2) | 1,477 | 1,462 | 16,327 | |||||||||||
(Gain) loss on derivative instruments(1) | 25,677 | (67,337) | 57,642 | (86,063) | |||||||||||
Gain on sale of equity method investment | (66,412) | — | (66,412) | — | |||||||||||
Stock-based compensation expense | 6,808 | 15,516 | 30,780 | 33,147 | |||||||||||
Severance expense | — | — | 2,521 | 28 | |||||||||||
Interest expense related to income tax reserves | — | (538) | (3,052) | 3,116 | |||||||||||
Tax effect on selected items | 7,739 | 11,619 | (5,233) | 7,637 | |||||||||||
Adjusted net income | $ | 120,750 | $ | 235,781 | $ | 698,778 | $ | 531,235 | |||||||
As reported - earnings per share | $ | 0.36 | $ | 0.64 | $ | 1.64 | $ | 1.25 | |||||||
Per share impact of selected items | (0.06) | (0.09) | 0.04 | (0.06) | |||||||||||
Adjusted earnings per share | $ | 0.30 | $ | 0.55 | $ | 1.68 | $ | 1.19 | |||||||
Weighted-average common shares outstanding | 404,581 | 430,978 | 415,514 | 445,538 |
_______________________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as Adjusted Net Income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our profitability and the efficiency with which we have employed capital over time. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
Twelve Months Ended | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Interest expense, net | $ | 54,952 | $ | 73,201 | ||||
Interest expense related to income tax reserves (1) | 3,052 | (3,116) | ||||||
Tax benefit | (13,241) | (16,004) | ||||||
After-tax interest expense, net (A) | 44,763 | 54,081 | ||||||
As reported - net income | 681,070 | 557,043 | ||||||
Adjustments to as reported - net income, net of tax | 17,708 | (25,808) | ||||||
Adjusted net income (B) | 698,778 | 531,235 | ||||||
Adjusted net income before interest expense, net (A + B) | $ | 743,541 | $ | 585,316 | ||||
Total debt - beginning | $ | 1,226,104 | $ | 1,521,891 | ||||
Stockholders' equity - beginning | 2,088,159 | 2,523,905 | ||||||
Capital employed - beginning | 3,314,263 | 4,045,796 | ||||||
Total debt - ending | 1,220,025 | 1,226,104 | ||||||
Stockholders' equity - ending | 2,151,487 | 2,088,159 | ||||||
Capital employed - ending | 3,371,512 | 3,314,263 | ||||||
Average capital employed (C) | $ | 3,342,888 | $ | 3,680,030 | ||||
Return on average capital employed (ROCE) (A + B) / C | 22.2 | % | 15.9 | % |
_______________________________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | ||||||||||||
Net cash provided by operating activities | $ | 262,980 | $ | 316,051 | $ | 1,445,791 | $ | 1,104,903 | ||||||||
Changes in assets and liabilities | 14,564 | 176,753 | (85,026) | 163,460 | ||||||||||||
Discretionary cash flow | 277,544 | 492,804 | 1,360,765 | 1,268,363 | ||||||||||||
Capital expenditures | (167,672) | (246,967) | (788,368) | (894,470) | ||||||||||||
Investment in equity method investments | (361) | (4,397) | (9,338) | (77,263) | ||||||||||||
Free cash flow | $ | 109,511 | $ | 241,440 | $ | 563,059 | $ | 296,630 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net income | $ | 146,940 | $ | 275,044 | $ | 681,070 | $ | 557,043 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 14,650 | 15,624 | 54,952 | 73,201 | |||||||||||
Other expense | 144 | 116 | 574 | 463 | |||||||||||
Income tax expense | 60,475 | 49,893 | 219,154 | 141,094 | |||||||||||
Depreciation, depletion and amortization | 106,439 | 129,269 | 405,733 | 417,479 | |||||||||||
Exploration | 5,241 | 45,654 | 20,270 | 113,820 | |||||||||||
(Gain) loss on sale of assets | (2) | 1,477 | 1,462 | 16,327 | |||||||||||
Non-cash (gain) loss on derivative instruments | 25,677 | (67,337) | 57,642 | (86,063) | |||||||||||
Earnings on equity method investments | (69,302) | (2,146) | (80,496) | (1,137) | |||||||||||
Equity method investment distributions | 3,187 | 1,296 | 17,453 | 1,296 | |||||||||||
Stock-based compensation | 6,808 | 15,516 | 30,780 | 33,147 | |||||||||||
EBITDAX | $ | 300,257 | $ | 464,406 | $ | 1,408,594 | $ | 1,266,670 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | December 31, 2019 | December 31, 2018 | |||||
Current portion of long-term debt | $ | 87,000 | $ | — | |||
Long-term debt, net | 1,133,025 | 1,226,104 | |||||
Total debt | $ | 1,220,025 | $ | 1,226,104 | |||
Stockholders' equity | 2,151,487 | 2,088,159 | |||||
Total capitalization | $ | 3,371,512 | $ | 3,314,263 | |||
Total debt | $ | 1,220,025 | $ | 1,226,104 | |||
Less: Cash and cash equivalents | (200,227) | (2,287) | |||||
Net debt | $ | 1,019,798 | $ | 1,223,817 | |||
Net debt | $ | 1,019,798 | $ | 1,223,817 | |||
Stockholders' equity | 2,151,487 | 2,088,159 | |||||
Total adjusted capitalization | $ | 3,171,285 | $ | 3,311,976 | |||
Total debt to total capitalization ratio | 36.2 | % | 37.0 | % | |||
Less: Impact of cash and cash equivalents | 4.0 | % | — | % | |||
Net debt to adjusted capitalization ratio | 32.2 | % | 37.0 | % |
Capital Expenditures | ||||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | |||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | ||||||||||||
Cash paid for capital expenditures | $ | 167,672 | $ | 246,967 | $ | 788,368 | $ | 894,470 | ||||||||
Change in accrued capital costs | (4,306) | 17,326 | (2,870) | 19,346 | ||||||||||||
Exploratory dry hole cost | (2,220) | (41,316) | (2,236) | (97,741) | ||||||||||||
Capital expenditures | $ | 161,146 | $ | 222,977 | $ | 783,262 | $ | 816,075 |
Finding and Development Costs
Drill-Bit Finding and Development Cost is defined as costs incurred in exploration and development activities as defined by GAAP divided by reserve extensions, discoveries and other additions. All-Sources Finding and Development Cost is defined as costs incurred in property acquisition, exploration and development activities, as defined by GAAP, divided by the total of reserve extensions, discoveries and other additions and revision of prior estimates. Drill-Bit Finding and Development Cost and All-Sources Finding and Development Cost are presented based on management's belief that these non-GAAP measures are useful information to investors to evaluate how much it costs to add proved reserves. These calculations do not include the future development costs required for the development of proved undeveloped reserves and may not be comparable to similarly titled measurements used by other companies.
Year Ended December 31, | |||||||
2019 | 2018 | ||||||
Costs incurred in oil and gas property acquisition, exploration and development activities (In thousands) | |||||||
Exploration costs | $ | 20,270 | $ | 94,309 | |||
Development costs | 761,326 | 778,574 | |||||
Exploration and development costs (A) | 781,596 | 872,883 | |||||
Property acquisition costs, unproved | 6,072 | 29,851 | |||||
Total costs incurred (B) | 787,668 | 902,734 | |||||
Extensions, discoveries and other additions (Bcfe) (C) | 2,116 | 2,244 | |||||
Revision of prior estimates (Bcfe) (D) | 47 | 780 | |||||
Drill-bit finding and development costs ($ per Mcfe) (A) / (C) | $ | 0.37 | $ | 0.39 | |||
All-sources finding and development costs ($ per Mcfe) (B) / (C + D) | $ | 0.36 | $ | 0.30 |
Pre-Tax Present Value of Future Net Cash Flows Calculation and Reconciliation
Pre-Tax Present Value of Future Net Cash Flows, discounted at 10% annual rate (Pre-Tax PV-10), is defined as Standardized Measure of Discounted Future Net Cash Flows plus Future Income Tax Expenses, discounted at 10% annual rate. Year-end Pre-Tax PV-10 value is presented based on our belief that this non-GAAP measure is useful information to investors and creditors when comparing Pre-Tax PV-10 values as a basis for comparison of our relative size and value of reserves as compared with other companies. Pre-Tax PV-10 is not a measure under GAAP and should not be considered as alternative to Standardized Measure of Discounted Future Net Cash Flows, as defined by GAAP.
(In thousands) | December 31, 2019 | December 31, 2018 | |||||
Standardized Measure of Discounted Future Net Cash Flows | $ | 5,861,117 | $ | 6,483,308 | |||
Plus: Future Income Tax Expenses, discounted at 10% annual rate | 1,639,288 | 1,651,488 | |||||
Pre-tax Present Value of Future Net Cash Flows, discounted at 10% annual rate | $ | 7,500,405 | $ | 8,134,796 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-fourth-quarter-and-full-year-2019-results-301008782.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 4, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today provided an operational update for the fourth quarter of 2019 and announced updated 2020 guidance. Additionally, the Company provided an update on its share repurchase program.
Fourth Quarter 2019 Operational Update
Cabot expects production for the fourth quarter of 2019 to be approximately 2,457 million cubic feet equivalent (Mmcfe) per day, exceeding the high-end of the Company's guidance range for the quarter. Natural gas price realizations, including the impact of derivatives, are expected to be $2.15 per thousand cubic feet (Mcf) in the fourth quarter of 2019. Excluding the impact of derivatives, natural gas price realizations for the quarter are expected to be $2.05 per Mcf, representing a $0.45 discount to NYMEX settlement prices. Additionally, Cabot expects to incur between $160 and $170 million of capital expenditures during the fourth quarter of 2019.
Updated 2020 Guidance
Given the continued weakness in natural gas prices throughout the winter heating season and the corresponding degradation in the NYMEX futures curve for 2020, Cabot has elected to adopt its previously disclosed maintenance capital plan as the Company's official budget for 2020. This plan is expected to deliver an average net production rate of approximately 2.4 billion cubic feet (Bcf) per day for the year from a capital program of $575 million. This plan assumes a moderate amount of curtailments throughout the year based on an expectation of normal pipeline maintenance, higher line pressures, and weaker spot market prices. At a $2.25 average NYMEX price, this program is expected to deliver between $275 and $300 million of free cash flow and generate a return on capital employed between 11 and 12 percent. "Our decision to reduce capital spending by approximately 27 percent year-over-year highlights our continued commitment to disciplined capital allocation. We believe that by substantially reducing our drilling and completion activity in 2020, we are taking the necessary steps to adapt to the current uncertainty in the natural gas markets and we are prepared to maintain these reduced activity levels as long as this lower price environment persists. While we still expect to generate positive free cash flow, cover our dividend commitments, deliver corporate returns that exceed our cost of capital, and maintain a strong balance sheet in the current price environment, we are by no means immune to the significant decline in natural gas prices we have experienced since May of last year. We are encouraged by the reduction in horizontal rig counts across the Marcellus, Utica and Haynesville—which are collectively down 39 percent since their recent peaks in the second quarter of 2019—and are hopeful that market forces will continue to move natural gas supply and demand toward a more sustainable balance; however, we will continue to evaluate the potential for additional capital reductions if prices erode further," stated Dan O. Dinges, Chairman, President and Chief Executive Officer.
Share Repurchase Program Update
During the fourth quarter of 2019, Cabot repurchased 10 million shares at a weighted-average share price of $17.22, representing an additional 5 million shares repurchased subsequent to the Company's previous update on November 18, 2019. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 14 percent to approximately 398 million shares. The Company currently has 11 million remaining shares authorized under its share repurchase program (or approximately three percent of its current shares outstanding).
Fourth Quarter and Year-End 2019 Earnings Release and Conference Call
Cabot will host its fourth quarter and year-end 2019 earnings conference call on Friday, February 21, 2020 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results on Thursday, February 20, 2020 after the market closes. To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 3, 2020 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of ten cents ($0.10) per share on the Company's common stock. The dividend will be paid on February 7, 2020 to all shareholders of record as of the close of business on January 24, 2020.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300981025.html
SOURCE Cabot Oil & Gas Corporation
DALLAS, Nov. 20, 2019 /PRNewswire/ -- Cushing® Asset Management, LP, and Swank Capital, LLC, announce today the upcoming rebalancing of The Cushing® Energy Supply Chain Index (the "Index") as part of normal index operations. After the markets close on November 29, 2019, the constituents of the Index will be rebalanced, and the following changes will become effective on December 2, 2019:
Constituents added:
Energy Transfer LP (NYSE: ET)
Shell Midstream Partners, L.P. (NYSE: SHLX)
Sealed Air Corporation (NYSE: SEE)
Cabot Oil & Gas Corporation (NYSE: COG)
Constituents removed:
NGL Energy Partners LP (NYSE: NGL)
BP Midstream Partners LP (NYSE: BPMP)
ABOUT THE CUSHING® ENERGY SUPPLY CHAIN INDEX
The Cushing® Energy Supply Chain Index tracks the performance of widely held companies engaged in exploration and production, refining and marketing, or storage and transportation of oil, natural gas, coal and consumable fuels; oil and natural gas equipment and services companies; and companies that extract and/or manufacture materials. Constituents of the Index are weighted based on current yield. The Index price level is calculated by S&P Dow Jones Indices and reported on a real-time basis under the Bloomberg ticker "CSCI".
ABOUT CUSHING® ASSET MANAGEMENT AND SWANK CAPITAL
Cushing® Asset Management, LP ("Cushing"), a subsidiary of Swank Capital, LLC, is an SEC-registered investment adviser headquartered in Dallas, Texas. Cushing serves as investment adviser to affiliated funds and managed accounts, providing active management in markets where inefficiencies exist.
Cushing is also dedicated to serving the needs of investors by sponsoring a variety of benchmarks, including The Cushing® 30 MLP Index (Bloomberg Ticker: MLPX), The Cushing® 30 MLP Market Cap Index (Bloomberg Ticker: CMCI), The Cushing® MLP High Income Index (Bloomberg Ticker: MLPY), The Cushing® Energy Index (Bloomberg Ticker: CENI), The Cushing® Transportation Index (Bloomberg Ticker: CTRI) and The Cushing® Utility Index (Bloomberg Ticker: CUTI). For more information, please visit http://www.cushingasset.com/indices.
Contact:
Brian Atwood
214-692-6334
www.cushingasset.com
The Cushing® Energy Supply Chain Index (the "Index") is the exclusive property of Swank Capital, LLC, and Cushing Asset Management, LP, which have contracted with S&P Opco, LLC (a subsidiary of S&P Dow Jones Indices LLC) ("S&P Dow Jones Indices") to calculate and maintain the Index. S&P® is a registered trademark of Standard & Poor's Financial Services LLC ("SPFS"); Dow Jones® is a registered trademark of Dow Jones Trademark Holdings LLC ("Dow Jones"); and, these trademarks have been licensed to S&P Dow Jones Indices. "Calculated by S&P Dow Jones Indices" and its related stylized mark(s) have been licensed for use by Cushing Asset Management, LP. Neither S&P Dow Jones Indices, SPFS, Dow Jones nor any of their affiliates sponsor and promote the Index and none shall be liable for any errors or omissions in calculating the Index.
CUSH-CSCI
View original content:http://www.prnewswire.com/news-releases/cushing-asset-management-and-swank-capital-announce-rebalancing-of-the-cushing-energy-supply-chain-index-300961777.html
SOURCE Cushing® Asset Management, LP; Swank Capital, LLC
HOUSTON, Nov. 18, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today it has completed the previously announced divestiture of its 20 percent ownership interest in Meade Pipeline Co LLC ("Meade") and provided an update on its share repurchase program.
Completion of Meade Divestiture
On November 13, 2019, Cabot completed the divestiture of its 20 percent ownership interest in Meade for $256 million, excluding customary closing adjustments. "Proceeds from this divestiture will allow Cabot to continue to enhance shareholder value through an ongoing opportunistic share repurchase program, while also providing the Company with increased financial strength in a challenging natural gas price environment," highlighted Dan O. Dinges, Chairman, President and Chief Executive Officer.
Share Repurchase Program Update
"Subsequent to our third quarter earnings release, we were active in our share repurchase program in anticipation of the proceeds from the Meade divestiture," stated Dinges. Cabot has repurchased 5.0 million shares at a weighted-average share price of $17.84 during the fourth quarter of 2019. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 13 percent to 402.9 million shares. The Company currently has 16.0 million remaining shares authorized under its share repurchase program (or approximately four percent of its current shares outstanding). Dinges added, "Year-to-date, we have returned over $580 million of capital to shareholders through dividends and share repurchases, representing over 110 percent of the midpoint of our free cash flow guidance for the year and far exceeding our target of returning at least 50 percent of annual free cash flow to shareholders. We plan to remain active with our opportunistic share repurchases, which are supported by our expectation for continued free cash flow generation, even in the lows of the natural gas price cycle."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-completes-divestiture-of-its-ownership-interest-in-meade-pipeline-co-llc-provides-update-on-share-repurchase-program-300959441.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 24, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the third quarter of 2019.
"In the third quarter of 2019, Cabot increased free cash flow by over 150 percent compared to the prior-year period, driven by higher production volumes, lower per unit operating expenses, improved basis differentials, and reduced capital spending, despite a 23 percent reduction in NYMEX benchmark prices," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our results highlight the resiliency of Cabot's business model and our ability to deliver strong financial results even in the lows of the natural gas price cycle, while continuing to return capital to our shareholders."
Third Quarter 2019 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and ROCE.
Third Quarter 2019 Financial Results
Third quarter 2019 daily production was 2,399 Mmcfe per day (100 percent natural gas), exceeding the midpoint of the Company's guidance range and representing an 18 percent increase relative to the third quarter of 2018.
Third quarter 2019 net income was $90.4 million, or $0.22 per share, compared to $122.3 million, or $0.28 per share, in the prior-year period. Third quarter 2019 adjusted net income (non-GAAP) was $119.7 million, or $0.29 per share, compared to $108.9 million, or $0.25 per share, in the prior-year period. Third quarter 2019 EBITDAX (non-GAAP) was $283.6 million, compared to $291.6 million in the prior-year period.
Third quarter 2019 net cash provided by operating activities was $270.9 million, compared to $242.2 million in the prior-year period. Third quarter 2019 discretionary cash flow (non-GAAP) was $275.5 million, compared to $298.8 million in the prior-year period. Third quarter 2019 free cash flow (non-GAAP) was $72.4 million, compared to $28.6 million in the prior-year period.
Third quarter 2019 natural gas price realizations, including the impact of derivatives, were $2.11 per thousand cubic feet (Mcf), a decrease of 11 percent compared to the prior-year period. Excluding the impact of derivatives, third quarter 2019 natural gas price realizations were $1.89 per Mcf, representing a $0.34 discount to NYMEX settlement prices compared to a $0.54 discount in the prior-year period.
Third quarter 2019 operating expenses (including interest expense) decreased to $1.43 per Mcfe, a 15 percent improvement compared to the prior-year period. All operating expenses per unit decreased relative to the prior-year period except for direct operations and taxes other than income, which were both flat to the third quarter of 2018.
Cabot incurred a total of $197.5 million of capital expenditures in the third quarter of 2019 including $190.5 million of drilling and facilities capital, $2.0 million of leasehold acquisition capital, and $5.0 million of other capital. Additionally, the Company contributed $3.8 million to its equity method pipeline investments. See the supplemental table at the end of this press release reconciling the capital expenditures during the third quarter of 2019.
Year-To-Date 2019 Financial Results
Daily production for the nine-month period ended September 30, 2019 was 2,342 Mmcfe per day (100 percent natural gas), representing a 21 percent increase relative to the prior-year period.
For the nine-month period ended September 30, 2019, net income was $534.1 million, or $1.27 per share, compared to $282.0 million, or $0.63 per share, for the prior-year period. Adjusted net income (non-GAAP) for the nine-month period ended September 30, 2019 was $578.0 million, or $1.38 per share, compared to $295.3 million, or $0.66 per share, for the prior-year period. EBITDAX (non-GAAP) for the nine-month period ended September 30, 2019 was $1,108.3 million, compared to $802.3 million for the prior-year period.
For the nine-month period ended September 30, 2019, net cash provided by operating activities was $1,182.8 million, compared to $788.9 million for the prior-year period. Discretionary cash flow (non-GAAP) for the nine-month period ended September 30, 2019 was $1,083.2 million, compared to $775.6 million for the prior-year period. Free cash flow (non-GAAP) was $453.5 million for the nine-month period ended September 30, 2019, compared to $55.2 million for the prior-year period. ROCE (non-GAAP) improved to 25.2 percent for the trailing twelve months ended September 30, 2019, compared to 10.8 percent for the trailing twelve months ended September 30, 2018.
Natural gas price realizations, including the impact of derivatives, were $2.56 per Mcf for the nine-month period ended September 30, 2019, an increase of 10 percent compared to the prior-year period.
For the nine-month period ended September 30, 2019, operating expenses (including interest expense) decreased to $1.44 per Mcfe, a 16 percent improvement compared to the prior-year period. The decrease in operating expenses per unit was primarily driven by a reduction in exploration and depreciation, depletion, and amortization, in addition to improvements in direct operations, transportation and gathering, taxes other than income, general and administrative, and interest expense.
Cabot incurred a total of $622.1 million of capital expenditures during the nine-month period ended September 30, 2019 including $605.9 million of drilling and facilities capital, $5.3 million of leasehold acquisition capital, and $10.9 million of other capital. Additionally, the Company contributed $9.0 million to its equity method pipeline investments during the nine-month period ended September 30, 2019. See the supplemental table at the end of this press release reconciling the capital expenditures during the nine-month period ended September 30, 2019.
Dividend Increase
Cabot's Board of Directors has approved an 11 percent increase in its quarterly cash dividend to $0.10 per share on the Company's common stock, resulting in the fifth dividend increase since May 2017. The dividend will be paid on November 15, 2019 to all shareholders of record as of the close of business on November 6, 2019. "We remain committed to increasing our return of capital to shareholders through the combination of a growing dividend and opportunistic share repurchases," highlighted Dinges. "Our outlook for the continued generation of significant free cash flow over the coming years, even at natural gas prices that are materially below the current forward curve, will allow Cabot to remain a sector leader in returning capital to shareholders."
Share Repurchase Program Update
As previously announced in its September 30, 2019 press release, Cabot repurchased 10.5 million shares at a weighted-average share price of $18.21 during the third quarter of 2019. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 12 percent to 407.9 million shares. The Company currently has 21.0 million remaining shares authorized under its share repurchase program (or approximately five percent of its current shares outstanding).
Financial Position and Liquidity
As of September 30, 2019, Cabot had total debt of $1.2 billion and cash on hand of $82.3 million. The Company's net debt-to-adjusted capitalization ratio and net debt-to-trailing twelve months EBITDAX ratio were 33.9 percent and 0.7x, respectively, compared to 37.0 percent and 1.0x as of December 31, 2018. The Company currently has no debt outstanding under its credit facility, resulting in approximately $1.6 billion of liquidity.
Fourth Quarter and Full-Year 2019 Guidance Update
Cabot has provided its fourth quarter 2019 production guidance range of 2,375 to 2,425 Mmcfe per day. The Company has also updated its full-year 2019 production growth guidance to 17 percent, which is the midpoint of the prior guidance range of 16 to 18 percent. This represents 25 percent growth in production per debt-adjusted share for the year. Cabot has also reaffirmed its 2019 capital budget range of $800 million to $820 million.
Additionally, the Company has updated its full-year 2019 NYMEX price assumption to $2.60 per Mmbtu, which reflects the ten months of actual NYMEX settlements to date and the current forward prices for the remaining two months of the year. The Company has also reaffirmed its estimated key financial metrics for the year based on this NYMEX price assumption in the table below.
Estimated 2019 Key Financial Metrics (1) | $2.60 NYMEX | |||||
Adjusted Earnings Per Share Growth (%) | 38% - 42% | |||||
Free Cash Flow ($mm) | $500 - $525 | |||||
Return on Capital Employed (%) | 20% - 22% | |||||
(1) Includes the impact of derivative instruments |
For further disclosure on Cabot's expected fourth quarter 2019 natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Preliminary Full-Year 2020 Guidance
In the Company's second quarter 2019 earnings release, Cabot provided a preliminary 2020 plan ("growth scenario") that is expected to generate full-year production growth of five percent (seven to eight percent growth in full-year production per debt-adjusted share) based on a preliminary capital budget range of $700 million to $725 million, including non-drilling and completion capital. This plan was predicated on a 2020 NYMEX price assumption of $2.50 per Mmbtu. Subsequent to the second quarter earnings release, the 2020 NYMEX forward curve continued to decline to levels below the Company's original budget price assumption. As a result, in addition to its initial preliminary 2020 guidance, Cabot is also evaluating a maintenance capital plan ("maintenance scenario") that holds fourth quarter 2020 production levels flat to the midpoint of the fourth quarter 2019 production guidance range (two to three percent growth in full-year production per debt-adjusted share) based on a $575 million capital program, including non-drilling and completion capital. The growth scenario delivers a fourth quarter 2020 exit growth rate of five percent and is designed to position Cabot for continued growth in 2021, while the maintenance scenario is designed to position the Company for a continued flat production profile in 2021. Both scenarios assume a moderate amount of curtailments during the shoulder seasons based on an expectation of normal pipeline maintenance, higher line pressures, and weaker spot market prices. Cabot will continue to evaluate both scenarios and assess the impact of the winter withdrawal season on the Company's 2020 natural gas price outlook before issuing formal 2020 guidance in the year-end earnings release in February. "We continue to maintain a cautiously optimistic outlook for the natural gas markets in 2020, driven in large part by our expectation for a pronounced decrease in operating activity across North American natural gas basins due to continued price weakness," said Dinges. "However, we are prepared to modify our 2020 plan early next year in response to lower anticipated natural gas prices, if necessary, with a continued focus on delivering a combination of strong free cash flow generation, high return on capital employed, consistent return of capital to shareholders including our recent dividend increase, low financial leverage, and growth in production and reserves per share—all of which are provided by both of the 2020 scenarios we are currently evaluating."
Conference Call Webcast
A conference call is scheduled for Friday, October 25, 2019, at 9:30 a.m. Eastern Time to discuss third quarter 2019 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, pipeline projects, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 220.7 | 186.5 | 639.3 | 523.6 | |||||||||||
Crude oil and condensate (Mbbl) | — | — | — | 754.0 | |||||||||||
Natural gas liquids (NGLs) (Mbbl) | — | — | — | 75.1 | |||||||||||
Equivalent production (Bcfe) | 220.7 | 186.5 | 639.3 | 528.6 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,399 | 2,029 | 2,342 | 1,936 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 2.11 | $ | 2.36 | $ | 2.56 | $ | 2.32 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 1.89 | $ | 2.36 | $ | 2.38 | $ | 2.33 | |||||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 63.68 | |||||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 64.68 | |||||||
NGL ($/Bbl) | $ | — | $ | — | $ | — | $ | 21.49 | |||||||
AVERAGE UNIT COSTS ($/Mcfe) | |||||||||||||||
Direct operations | $ | 0.09 | $ | 0.09 | $ | 0.09 | $ | 0.10 | |||||||
Transportation and gathering | 0.66 | 0.69 | 0.66 | 0.67 | |||||||||||
Taxes other than income | 0.02 | 0.02 | 0.02 | 0.03 | |||||||||||
Exploration | 0.02 | 0.05 | 0.02 | 0.13 | |||||||||||
Depreciation, depletion and amortization | 0.50 | 0.65 | 0.47 | 0.55 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.07 | 0.08 | 0.08 | 0.09 | |||||||||||
Stock-based compensation | 0.01 | 0.03 | 0.04 | 0.03 | |||||||||||
Interest expense | 0.06 | 0.08 | 0.06 | 0.11 | |||||||||||
$ | 1.43 | $ | 1.69 | $ | 1.44 | $ | 1.71 | ||||||||
WELLS DRILLED (1) | |||||||||||||||
Gross | 22 | 21 | 71 | 60 | |||||||||||
Net | 22.0 | 21.0 | 71.0 | 60.0 | |||||||||||
WELLS COMPLETED (1) | |||||||||||||||
Gross | 29 | 27 | 71 | 61 | |||||||||||
Net | 29.0 | 27.0 | 71.0 | 61.0 |
____________________________________________________________ | |
(1) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 418,133 | $ | 440,835 | $ | 1,521,789 | $ | 1,217,603 | |||||||
Crude oil and condensate | — | — | — | 48,722 | |||||||||||
Gain (loss) on derivative instruments | 11,060 | (3,537) | 82,966 | (1,628) | |||||||||||
Brokered natural gas | — | 105,849 | — | 203,375 | |||||||||||
Other | (82) | 2,026 | 154 | 3,775 | |||||||||||
429,111 | 545,173 | 1,604,909 | 1,471,847 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 19,181 | 17,030 | 55,608 | 52,757 | |||||||||||
Transportation and gathering | 145,681 | 129,534 | 424,703 | 355,848 | |||||||||||
Brokered natural gas | — | 93,405 | — | 178,437 | |||||||||||
Taxes other than income | 4,607 | 2,852 | 14,094 | 15,434 | |||||||||||
Exploration | 4,481 | 10,049 | 15,029 | 68,166 | |||||||||||
Depreciation, depletion and amortization | 110,889 | 121,172 | 299,294 | 288,210 | |||||||||||
General and administrative (excluding stock-based compensation) | 16,272 | 14,235 | 48,398 | 48,382 | |||||||||||
Stock-based compensation(1) | 2,119 | 6,489 | 23,972 | 17,631 | |||||||||||
303,230 | 394,766 | 881,098 | 1,024,865 | ||||||||||||
Earnings (loss) on equity method investments | 3,860 | (11) | 11,194 | (1,009) | |||||||||||
Gain (loss) on sale of assets | 36 | 25,655 | (1,464) | (14,850) | |||||||||||
INCOME FROM OPERATIONS | 129,777 | 176,051 | 733,541 | 431,123 | |||||||||||
Interest expense, net | 13,554 | 14,191 | 40,302 | 57,577 | |||||||||||
Other expense | 143 | 115 | 430 | 347 | |||||||||||
Income before income taxes | 116,080 | 161,745 | 692,809 | 373,199 | |||||||||||
Income tax expense | 25,722 | 39,408 | 158,679 | 91,201 | |||||||||||
NET INCOME | $ | 90,358 | $ | 122,337 | $ | 534,130 | $ | 281,998 | |||||||
Earnings per share - Basic | $ | 0.22 | $ | 0.28 | $ | 1.27 | $ | 0.63 | |||||||
Weighted-average common shares outstanding | 412,456 | 440,772 | 419,199 | 450,445 |
______________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | September 30, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 421,679 | $ | 544,545 | |||
Properties and equipment, net (Successful efforts method) | 3,787,581 | 3,463,606 | |||||
Other assets | 233,405 | 190,678 | |||||
$ | 4,442,665 | $ | 4,198,829 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 294,785 | $ | 287,264 | |||
Long-term debt, net (excluding current maturities) | 1,132,790 | 1,226,104 | |||||
Deferred income taxes | 647,473 | 458,597 | |||||
Other liabilities | 154,041 | 138,705 | |||||
Stockholders' equity | 2,213,576 | 2,088,159 | |||||
$ | 4,442,665 | $ | 4,198,829 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income | $ | 90,358 | $ | 122,337 | $ | 534,130 | $ | 281,998 | |||||||
Deferred income tax expense | 36,350 | 64,823 | 188,997 | 131,799 | |||||||||||
(Gain) loss on sale of assets | (36) | (25,655) | 1,464 | 14,850 | |||||||||||
Exploratory dry hole cost | — | 5,340 | 16 | 56,425 | |||||||||||
(Gain) loss on derivative instruments | (11,060) | 3,537 | (82,966) | 1,628 | |||||||||||
Net cash received (paid) in settlement of derivative instruments | 46,555 | (41) | 114,931 | (20,354) | |||||||||||
Income charges not requiring cash | 113,305 | 128,422 | 326,649 | 309,212 | |||||||||||
Changes in assets and liabilities | (4,598) | (56,569) | 99,590 | 13,294 | |||||||||||
Net cash provided by operating activities | 270,874 | 242,194 | 1,182,811 | 788,852 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (199,196) | (260,232) | (620,696) | (647,503) | |||||||||||
Proceeds from sale of assets | 55 | 28,657 | 2,401 | 675,525 | |||||||||||
Investment in equity method investments | (3,846) | (9,961) | (8,977) | (72,866) | |||||||||||
Distribution of investment from equity method investments | 898 | — | 1,656 | — | |||||||||||
Net cash used in investing activities | (202,089) | (241,536) | (625,616) | (44,844) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | — | (237,000) | (7,000) | (237,000) | |||||||||||
Treasury stock repurchases | (190,808) | (162,071) | (347,446) | (581,725) | |||||||||||
Dividends paid | (37,025) | (26,467) | (104,722) | (81,185) | |||||||||||
Tax withholdings on vesting of stock awards | (30) | (37) | (10,587) | (8,068) | |||||||||||
Capitalized debt issuance costs | — | — | (7,411) | — | |||||||||||
Net cash used in financing activities | (227,863) | (425,575) | (477,166) | (907,978) | |||||||||||
Net (decrease) increase in cash and cash equivalents | $ | (159,078) | $ | (424,917) | $ | 80,029 | $ | (163,970) |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
As reported - net income | $ | 90,358 | $ | 122,337 | $ | 534,130 | $ | 281,998 | |||||||
Reversal of selected items: | |||||||||||||||
(Gain) loss on sale of assets | (36) | (25,655) | 1,464 | 14,850 | |||||||||||
(Gain) loss on derivative instruments(1) | 35,495 | 3,496 | 31,965 | (18,726) | |||||||||||
Stock-based compensation expense | 2,119 | 6,489 | 23,972 | 17,631 | |||||||||||
Severance expense | 398 | — | 2,521 | 28 | |||||||||||
Interest expense related to income tax reserves | — | (1,863) | (3,052) | 3,654 | |||||||||||
Tax effect on selected items | (8,672) | 4,127 | (12,986) | (4,104) | |||||||||||
Adjusted net income | $ | 119,662 | $ | 108,931 | $ | 578,014 | $ | 295,331 | |||||||
As reported - earnings per share | $ | 0.22 | $ | 0.28 | $ | 1.27 | $ | 0.63 | |||||||
Per share impact of selected items | 0.07 | (0.03) | 0.11 | 0.03 | |||||||||||
Adjusted earnings per share | $ | 0.29 | $ | 0.25 | $ | 1.38 | $ | 0.66 | |||||||
Weighted-average common shares outstanding | 412,456 | 440,772 | 419,199 | 450,445 |
___________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
Twelve Months Ended September 30, | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Interest expense, net | $ | 55,926 | $ | 77,987 | ||||
Interest expense related to income tax reserves (1) | 3,590 | (3,654) | ||||||
Tax benefit | (13,590) | (20,233) | ||||||
After-tax interest expense, net (A) | 45,926 | 54,100 | ||||||
As reported - net income | 809,174 | 237,558 | ||||||
Adjustments to as reported - net income, net of tax | 4,622 | 117,228 | ||||||
Adjusted net income (B) | 813,796 | 354,786 | ||||||
Adjusted net income before interest expense, net (A + B) | $ | 859,722 | $ | 408,886 | ||||
Total debt - beginning of twelve month period | $ | 1,285,848 | $ | 1,521,551 | ||||
Stockholders' equity - beginning of twelve month period | 2,094,147 | 2,644,594 | ||||||
Capital employed - beginning of twelve month period | 3,379,995 | 4,166,145 | ||||||
Total debt - end of twelve month period | 1,219,790 | 1,285,848 | ||||||
Stockholders' equity - end of twelve month period | 2,213,576 | 2,094,147 | ||||||
Capital employed - end of twelve month period | 3,433,366 | 3,379,995 | ||||||
Average capital employed (C) | $ | 3,406,681 | $ | 3,773,070 | ||||
Return on average capital employed (ROCE) (A+B) / C | 25.2 | % | 10.8 | % |
_______________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net cash provided by operating activities | $ | 270,874 | $ | 242,194 | $ | 1,182,811 | $ | 788,852 | |||||||
Changes in assets and liabilities | 4,598 | 56,569 | (99,590) | (13,294) | |||||||||||
Discretionary cash flow | 275,472 | 298,763 | 1,083,221 | 775,558 | |||||||||||
Capital expenditures | (199,196) | (260,232) | (620,696) | (647,503) | |||||||||||
Investment in equity method investments | (3,846) | (9,961) | (8,977) | (72,866) | |||||||||||
Free cash flow | $ | 72,430 | $ | 28,570 | $ | 453,548 | $ | 55,189 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended September 30, | Nine Months Ended September 30, | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net income | $ | 90,358 | $ | 122,337 | $ | 534,130 | $ | 281,998 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 13,554 | 14,191 | 40,302 | 57,577 | |||||||||||
Other expense | 143 | 115 | 430 | 347 | |||||||||||
Income tax expense | 25,722 | 39,408 | 158,679 | 91,201 | |||||||||||
Depreciation, depletion and amortization | 110,889 | 121,172 | 299,294 | 288,210 | |||||||||||
Exploration | 4,481 | 10,049 | 15,029 | 68,166 | |||||||||||
(Gain) loss on sale of assets | (36) | (25,655) | 1,464 | 14,850 | |||||||||||
Non-cash (gain) loss on derivative instruments | 35,495 | 3,496 | 31,965 | (18,726) | |||||||||||
(Earnings) loss on equity method investments | (3,860) | 11 | (11,194) | 1,009 | |||||||||||
Equity method investment distributions | 4,758 | — | 14,266 | — | |||||||||||
Stock-based compensation | 2,119 | 6,489 | 23,972 | 17,631 | |||||||||||
EBITDAX | $ | 283,623 | $ | 291,613 | $ | 1,108,337 | $ | 802,263 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | September 30, | December 31, | |||||
Current portion of long-term debt | $ | 87,000 | $ | — | |||
Long-term debt, net | 1,132,790 | 1,226,104 | |||||
Total debt | $ | 1,219,790 | $ | 1,226,104 | |||
Stockholders' equity | 2,213,576 | 2,088,159 | |||||
Total capitalization | $ | 3,433,366 | $ | 3,314,263 | |||
Total debt | $ | 1,219,790 | $ | 1,226,104 | |||
Less: Cash and cash equivalents | (82,316) | (2,287) | |||||
Net debt | $ | 1,137,474 | $ | 1,223,817 | |||
Net debt | $ | 1,137,474 | $ | 1,223,817 | |||
Stockholders' equity | 2,213,576 | 2,088,159 | |||||
Total adjusted capitalization | $ | 3,351,050 | $ | 3,311,976 | |||
Total debt to total capitalization ratio | 35.5 | % | 37.0 | % | |||
Less: Impact of cash and cash equivalents | 1.6 | % | — | % | |||
Net debt to adjusted capitalization ratio | 33.9 | % | 37.0 | % |
Capital Expenditures | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Cash paid for capital expenditures | $ | 199,196 | $ | 260,232 | $ | 620,696 | $ | 647,503 | |||||||
Change in accrued capital costs | (1,732) | 8,296 | 1,436 | 2,020 | |||||||||||
Exploratory dry hole cost | — | (5,340) | (16) | (56,425) | |||||||||||
Capital expenditures | $ | 197,464 | $ | 263,188 | $ | 622,116 | $ | 593,098 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-third-quarter-2019-results-increases-dividend-by-11-percent-300945188.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Sept. 30, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it plans to release third quarter 2019 financial and operating results on Thursday, October 24, 2019 after the market closes. The Company will host its third quarter 2019 earnings conference call on Friday, October 25, 2019 at 9:30 a.m. Eastern Time.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-third-quarter-2019-earnings-release-date-and-conference-call-300928001.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Sept. 30, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it has reached an agreement to sell its 20 percent ownership interest in Meade Pipeline Co LLC ("Meade") to a subsidiary of NextEra Energy Partners, LP (NYSE: NEP) for $256 million, or over 13 times expected 2019 EBITDAX (non-GAAP). Meade owns approximately 39 percent of the Central Penn Line, the greenfield pipeline segment of the Atlantic Sunrise project. This transaction is expected to close during the fourth quarter of 2019, subject to customary closing conditions and adjustments. Proceeds from this transaction, in addition to the Company's ongoing operating free cash flow, will allow Cabot to continue to enhance shareholder value by returning capital to shareholders through a combination of a growing dividend and an opportunistic share repurchase program.
BMO Capital Markets served as financial advisor to Cabot on this transaction.
Share Repurchase Program Update
During the third quarter of 2019, Cabot repurchased 10.5 million shares at a weighted-average share price of $18.21. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 12 percent to 407.9 million shares. The Company currently has 21.0 million remaining shares authorized under its share repurchase program (or approximately five percent of its current shares outstanding). "Based on our year-to-date share repurchases and our anticipated dividend payments for the year, the Company expects to return a minimum of approximately $490 million of capital to shareholders in 2019, far exceeding our minimum return of capital target of 50 percent of annual free cash flow," stated Dan O. Dinges, Chairman, President and Chief Executive Officer.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
Non-GAAP Financial Measures
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including property impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, gains and loss on equity method investments, cash distributions received from equity method investment and stock-based compensation expense. EBITDAX is presented based on management's belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Forward‐Looking Statements
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 26, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second quarter of 2019.
"During the quarter, Cabot successfully executed on its strategic plan of delivering a combination of positive free cash flow generation, improved return on capital employed, and disciplined growth in per share metrics, while continuing to return capital to shareholders through a combination of dividends and opportunistic share repurchases," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our success for the quarter was achieved despite NYMEX natural gas prices retreating to the lowest levels the industry has experienced since the second quarter of 2016, further highlighting Cabot's ability to deliver strong financial results throughout the natural gas price cycle."
Second Quarter 2019 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and ROCE.
Second Quarter 2019 Financial Results
Second quarter 2019 daily equivalent production was 2,349 Mmcfe per day (100 percent natural gas), meeting the high-end of the Company's guidance range and representing a 24 percent increase relative to the second quarter of 2018.
Second quarter 2019 net income was $181.0 million, or $0.43 per share, compared to net income of $42.4 million, or $0.09 per share, in the prior-year period. Second quarter 2019 adjusted net income (non-GAAP) was $150.6 million, or $0.36 per share, compared to adjusted net income of $57.9 million, or $0.13 per share, in the prior-year period. Second quarter 2019 EBITDAX (non-GAAP) was $311.1 million, compared to $232.1 million in the prior-year period.
Second quarter 2019 net cash provided by operating activities was $326.7 million, compared to $273.9 million in the prior-year period. Second quarter 2019 discretionary cash flow (non-GAAP) was $301.9 million, compared to $196.5 million in the prior-year period. Second quarter 2019 free cash flow (non-GAAP) was $72.7 million, compared to a free cash flow deficit of $62.0 million in the prior-year period.
Second quarter 2019 natural gas price realizations, including the impact of derivatives, were $2.27 per thousand cubic feet (Mcf), an increase of six percent compared to the prior-year period. Excluding the impact of derivatives, second quarter 2019 natural gas price realizations were $2.20 per Mcf, representing a $0.44 discount to NYMEX settlement prices compared to a $0.68 discount in the prior-year period.
Second quarter 2019 operating expenses (including financing) decreased to $1.41 per Mcfe, a 24 percent improvement compared to the prior-year period. The decrease in operating expenses per unit was primarily driven by a reduction in exploration expenses, in addition to improvements in direct operations; taxes other than income; depreciation, depletion, and amortization; general and administrative; and interest expense.
Cabot incurred a total of $220.4 million of capital expenditures in the second quarter of 2019 including $213.1 million of drilling and facilities capital, $2.6 million of leasehold acquisition capital, and $4.7 million of other capital. Additionally, the Company contributed $3.3 million to its equity method pipeline investments. See the supplemental table at the end of this press release reconciling the capital expenditures during the second quarter of 2019.
Year-To-Date 2019 Financial Results
Daily equivalent production for the six-month period ended June 30, 2019 was 2,313 Mmcfe per day (100 percent natural gas), representing a 22 percent increase relative to the prior-year period.
For the six-month period ended June 30, 2019, net income was $443.8 million, or $1.05 per share, compared to net income of $159.7 million, or $0.35 per share, for the prior-year period. Adjusted net income (non-GAAP) was $458.4 million, or $1.08 per share, compared to adjusted net income of $186.4 million, or $0.41 per share, for the prior-year period. EBITDAX (non-GAAP) for the six-month period ended June 30, 2019 was $824.7 million, compared to $510.7 million for the prior-year period.
For the six-month period ended June 30, 2019, net cash provided by operating activities was $911.9 million, compared to $546.7 million for the prior-year period. Discretionary cash flow (non-GAAP) for the six-month period ended June 30, 2019 was $807.7 million, compared to $476.8 million for the prior-year period. Free cash flow (non-GAAP) was $381.1 million for the six-month period ended June 30, 2019, compared to $26.6 million for the prior-year period. ROCE (non-GAAP) improved to 23.5 percent for the trailing twelve months ended June 30, 2019, compared to 8.5 percent for the trailing twelve months ended June 30, 2018.
Natural gas price realizations, including the impact of derivatives, were $2.80 per Mcf for the six-month period ended June 30, 2019, an increase of 22 percent compared to the prior-year period.
For the six-month period ended June 30, 2019, operating expenses (including financing) decreased to $1.45 per Mcfe, a 16 percent improvement compared to the prior-year period. The decrease in operating expenses per unit was primarily driven by a reduction in exploration expenses, in addition to improvements in direct operations; taxes other than income; depreciation, depletion, and amortization; general and administrative; and interest expense.
Cabot incurred a total of $424.7 million of capital expenditures during the six-month period ended June 30, 2019 including $415.4 million of drilling and facilities capital; $3.3 million of leasehold acquisition capital; and $6.0 million of other capital. Additionally, the Company contributed $5.1 million to its equity method pipeline investments during the six-month period ended June 30, 2019. See the supplemental table at the end of this press release reconciling the capital expenditures during the six-month period ended June 30, 2019.
Share Repurchase Program Update
During the second quarter of 2019, Cabot repurchased 5.1 million shares at a weighted-average share price of $24.63. Since reactivating the share repurchase program in the second quarter of 2017, Cabot has reduced its shares outstanding by over 10 percent to 418.4 million shares.
Additionally, the Board of Directors has authorized an increase in the Company's share repurchase program by 25.0 million shares, bringing the current remaining authorization to 31.5 million shares (or approximately eight percent of its current shares outstanding). All purchases will be made in accordance with applicable securities laws from time to time in open market or private transactions, depending on market conditions, and may be discontinued at any time. "Cabot remains committed to returning a minimum of 50 percent of its annual free cash flow to shareholders in any given year, while also preserving cash on the balance sheet to support continued opportunistic returns of capital, even in the lows of the natural gas price cycle," noted Dinges. "Our outlook for continued positive free cash flow generation provides us confidence that we will remain an industry leader in returning capital to shareholders."
Financial Position and Liquidity
As of June 30, 2019, Cabot had total debt of $1.2 billion and cash on hand of $241.4 million. The Company's net debt-to-adjusted capitalization ratio and net debt-to-trailing twelve months EBITDAX ratio were 29.4 percent and 0.6x, respectively, compared to 37.0 percent and 1.0x as of December 31, 2018. The Company currently has no debt outstanding under its credit facility, resulting in over $1.7 billion of liquidity.
Third Quarter and Full-Year 2019 Guidance Update
Cabot has provided its third quarter 2019 production guidance range of 2,360 to 2,410 Mmcfe per day. The Company has also adjusted its 2019 production growth guidance to a range of 16 to 18 percent (24 to 26 percent on a debt-adjusted per share basis) due in large part to a change in the operating plan resulting from a unique opportunity to acquire acreage adjacent to an eight-well pad, allowing the Company to increase the total lateral footage on the pad by approximately 28,000 feet (increasing the average lateral length per well from 8,950 feet to 12,450 feet). "This increase in lateral lengths will improve the capital efficiency and economics of the pad; however, the longer cycle time will result in a delay in the wells being placed on production, pushing out the production contribution from this pad to late December or early January," said Dinges.
Cabot has updated its 2019 capital budget to a range of $800 million to $820 million to reflect the incremental drilling and completion activity on the previously referenced eight-well pad and an increase in drilling activity for the year by four net wells resulting from continued efficiency gains on the Company's three fully-contracted drilling rigs.
Additionally, the Company has updated its NYMEX price assumption range for 2019 to reflect a tighter band of expected outcomes resulting from seven months of actual NYMEX settlements year-to-date. The Company has provided updated guidance on its estimated key financial metrics based on this NYMEX price assumption range in the table below.
Estimated 2019 Key Financial Metrics (1) | $2.60 NYMEX | $2.70 NYMEX | $2.80 NYMEX | |||
Adjusted Earnings Per Share Growth (%) | 38% - 42% | 45% - 49% | 52% - 56% | |||
Free Cash Flow ($mm) | $500 - $525 | $550 - $575 | $600 - $625 | |||
Return on Capital Employed (%) | 20% - 22% | 21% - 23% | 22% - 24% |
(1) Includes the impact of derivative instruments |
For further disclosure on Cabot's expected third quarter 2019 natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Preliminary Full-Year 2020 Guidance
Cabot has provided its preliminary 2020 production growth guidance of five percent (seven to eight percent on a debt-adjusted per share basis). This production growth is based on a preliminary capital budget range of $700 million to $725 million. The Company's 2020 program is expected to deliver $375 million to $400 million of free cash flow at a $2.50 NYMEX price and $525 million to $550 million of free cash flow at a $2.75 NYMEX price. "Based on our current outlook for the natural gas market, we believe a strategy that focuses on maximizing free cash flow generation through a reduction in capital spending and production growth will create the most value for our shareholders," explained Dinges. "This strategy, which is underpinned by disciplined capital allocation, will allow the Company to sustainably deliver a combination of free cash flow generation, high return on capital employed, consistent return of capital to shareholders, low leverage, and growth in production and reserves per share."
Conference Call Webcast
A conference call is scheduled for Friday, July 26, 2019, at 9:30 a.m. Eastern Time to discuss second quarter 2019 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
2019 | 2018 | 2019 | 2018 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 213.8 | 172.4 | 418.6 | 337.0 | |||||||||||
Crude oil and condensate (Mbbl) | — | — | — | 754.0 | |||||||||||
Natural gas liquids (NGLs) (Mbbl) | — | — | — | 75.1 | |||||||||||
Equivalent production (Bcfe) | 213.8 | 172.4 | 418.6 | 342.0 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,349 | 1,895 | 2,313 | 1,890 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 2.27 | $ | 2.15 | $ | 2.80 | $ | 2.29 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 2.20 | $ | 2.11 | $ | 2.64 | $ | 2.30 | |||||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 63.68 | |||||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | — | $ | — | $ | 64.68 | |||||||
NGL ($/Bbl) | $ | — | $ | — | $ | — | $ | 21.49 | |||||||
AVERAGE UNIT COSTS ($/Mcfe) | |||||||||||||||
Direct operations | $ | 0.08 | $ | 0.09 | $ | 0.09 | $ | 0.10 | |||||||
Transportation and gathering | 0.66 | 0.66 | 0.67 | 0.66 | |||||||||||
Taxes other than income | 0.02 | 0.03 | 0.02 | 0.04 | |||||||||||
Exploration | 0.02 | 0.32 | 0.03 | 0.17 | |||||||||||
Depreciation, depletion and amortization | 0.45 | 0.49 | 0.45 | 0.49 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.08 | 0.09 | 0.08 | 0.10 | |||||||||||
Stock-based compensation | 0.03 | 0.03 | 0.05 | 0.03 | |||||||||||
Interest expense | 0.07 | 0.14 | 0.06 | 0.13 | |||||||||||
$ | 1.41 | $ | 1.85 | $ | 1.45 | $ | 1.72 | ||||||||
WELLS DRILLED (1) | |||||||||||||||
Gross | 24 | 24 | 49 | 39 | |||||||||||
Net | 24.0 | 24.0 | 49.0 | 39.0 | |||||||||||
WELLS COMPLETED (1) | |||||||||||||||
Gross | 28 | 23 | 42 | 34 | |||||||||||
Net | 28.0 | 23.0 | 42.0 | 34.0 | |||||||||||
(1) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 470,482 | $ | 364,660 | $ | 1,103,656 | $ | 776,768 | |||||||
Crude oil and condensate | — | — | — | 48,722 | |||||||||||
Gain (loss) on derivative instruments | 63,649 | (3,668) | 71,906 | 1,909 | |||||||||||
Brokered natural gas | — | 92,576 | — | 97,526 | |||||||||||
Other | (14) | (121) | 236 | 1,749 | |||||||||||
534,117 | 453,447 | 1,175,798 | 926,674 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 18,093 | 15,657 | 36,427 | 35,727 | |||||||||||
Transportation and gathering | 141,689 | 114,189 | 279,022 | 226,314 | |||||||||||
Brokered natural gas | — | 80,082 | — | 85,032 | |||||||||||
Taxes other than income | 3,640 | 5,392 | 9,487 | 12,582 | |||||||||||
Exploration | 4,504 | 54,500 | 10,548 | 58,117 | |||||||||||
Depreciation, depletion and amortization | 96,147 | 84,910 | 188,405 | 167,038 | |||||||||||
General and administrative (excluding stock-based compensation) | 16,168 | 15,533 | 32,126 | 34,146 | |||||||||||
Stock-based compensation(1) | 6,721 | 5,695 | 21,853 | 11,142 | |||||||||||
286,962 | 375,958 | 577,868 | 630,098 | ||||||||||||
Earnings (loss) on equity method investments | 3,650 | (4) | 7,334 | (998) | |||||||||||
Gain (loss) on sale of assets | — | 544 | (1,500) | (40,505) | |||||||||||
INCOME FROM OPERATIONS | 250,805 | 78,029 | 603,764 | 255,073 | |||||||||||
Interest expense, net | 14,567 | 23,328 | 26,748 | 43,386 | |||||||||||
Other expense | 143 | 118 | 287 | 232 | |||||||||||
Income before income taxes | 236,095 | 54,583 | 576,729 | 211,455 | |||||||||||
Income tax expense | 55,086 | 12,152 | 132,957 | 51,793 | |||||||||||
NET INCOME | $ | 181,009 | $ | 42,431 | $ | 443,772 | $ | 159,662 | |||||||
Earnings per share - Basic | $ | 0.43 | $ | 0.09 | $ | 1.05 | $ | 0.35 | |||||||
Weighted-average common shares outstanding | 422,141 | 451,055 | 422,626 | 455,361 | |||||||||||
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | June 30, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 631,330 | $ | 544,545 | |||
Properties and equipment, net (Successful efforts method) | 3,699,575 | 3,463,606 | |||||
Other assets | 232,824 | 190,678 | |||||
$ | 4,563,729 | $ | 4,198,829 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 234,026 | $ | 287,264 | |||
Long-term debt, net | 1,219,555 | 1,226,104 | |||||
Deferred income taxes | 611,163 | 458,597 | |||||
Other liabilities | 154,181 | 138,705 | |||||
Stockholders' equity | 2,344,804 | 2,088,159 | |||||
$ | 4,563,729 | $ | 4,198,829 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income | $ | 181,009 | $ | 42,431 | $ | 443,772 | $ | 159,662 | |||||||
Deferred income tax expense | 64,645 | 2,689 | 152,647 | 66,976 | |||||||||||
(Gain) loss on sale of assets | — | (544) | 1,500 | 40,505 | |||||||||||
Exploratory dry hole cost | 3 | 51,145 | 16 | 51,085 | |||||||||||
Gain on derivative instruments | (63,649) | 3,668 | (71,906) | (1,909) | |||||||||||
Net cash received (paid) in settlement of derivative instruments | 15,397 | 5,819 | 68,377 | (20,312) | |||||||||||
Income charges not requiring cash | 104,477 | 91,289 | 213,343 | 180,790 | |||||||||||
Changes in assets and liabilities | 24,768 | 77,403 | 104,188 | 69,863 | |||||||||||
Net cash provided by operating activities | 326,650 | 273,900 | 911,937 | 546,660 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (225,850) | (231,014) | (421,500) | (387,271) | |||||||||||
Proceeds from sale of assets | — | 323 | 2,346 | 646,868 | |||||||||||
Investment in equity method investments | (3,303) | (27,487) | (5,131) | (62,905) | |||||||||||
Distribution of investment from equity method investments | 758 | — | 758 | — | |||||||||||
Net cash (used in) provided by investing activities | (228,395) | (258,178) | (423,527) | 196,692 | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | — | — | (7,000) | — | |||||||||||
Treasury stock repurchases | (125,260) | (212,520) | (156,638) | (419,654) | |||||||||||
Dividends paid | (38,092) | (27,071) | (67,697) | (54,718) | |||||||||||
Tax withholdings on vesting of stock awards | (987) | (65) | (10,557) | (8,033) | |||||||||||
Capitalized debt issuance costs | (7,411) | — | (7,411) | — | |||||||||||
Net cash used in financing activities | (171,750) | (239,656) | (249,303) | (482,405) | |||||||||||
Net (decrease) increase in cash and cash equivalents | $ | (73,495) | $ | (223,934) | $ | 239,107 | $ | 260,947 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2019 | 2018 | 2019 | 2018 | |||||||||||
As reported - net income | $ | 181,009 | $ | 42,431 | $ | 443,772 | $ | 159,662 | |||||||
Reversal of selected items: | |||||||||||||||
(Gain) loss on sale of assets | — | (544) | 1,500 | 40,505 | |||||||||||
(Gain) loss on derivative instruments(1) | (48,252) | 9,487 | (3,529) | (22,221) | |||||||||||
Stock-based compensation expense | 6,721 | 5,695 | 21,853 | 11,142 | |||||||||||
Severance expense | 2,124 | 28 | 2,124 | 28 | |||||||||||
Interest expense related to income tax reserves | — | 5,517 | (3,052) | 5,517 | |||||||||||
Tax effect on selected items | 8,998 | (4,751) | (4,315) | (8,232) | |||||||||||
Adjusted net income | $ | 150,600 | $ | 57,863 | $ | 458,353 | $ | 186,401 | |||||||
As reported - earnings per share | $ | 0.43 | $ | 0.09 | $ | 1.05 | $ | 0.35 | |||||||
Per share impact of selected items | (0.07) | 0.04 | 0.03 | 0.06 | |||||||||||
Adjusted earnings per share | $ | 0.36 | $ | 0.13 | $ | 1.08 | $ | 0.41 | |||||||
Weighted-average common shares outstanding | 422,141 | 451,055 | 422,626 | 455,361 | |||||||||||
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
Twelve Months Ended June 30, | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Interest expense, net | $ | 56,563 | $ | 84,127 | ||||
Interest expense related to income tax reserves (1) | 5,453 | (5,517) | ||||||
Tax benefit | (14,274) | (23,966) | ||||||
After-tax interest expense, net (A) | 47,742 | 54,644 | ||||||
As reported - net income | 841,153 | 132,808 | ||||||
Adjustments to as reported - net income, net of tax | (38,088) | 145,012 | ||||||
Adjusted net income (B) | 803,065 | 277,820 | ||||||
Adjusted net income before interest expense, net (A + B) | $ | 850,807 | $ | 332,464 | ||||
Total debt - beginning of twelve month period | $ | 1,522,572 | $ | 1,521,211 | ||||
Stockholders' equity - beginning of twelve month period | 2,154,174 | 2,642,031 | ||||||
Capital employed - beginning of twelve month period | 3,676,746 | 4,163,242 | ||||||
Total debt - end of twelve month period | 1,219,555 | 1,522,572 | ||||||
Stockholders' equity - end of twelve month period | 2,344,804 | 2,154,174 | ||||||
Capital employed - end of twelve month period | 3,564,359 | 3,676,746 | ||||||
Average capital employed (C) | $ | 3,620,553 | $ | 3,919,994 | ||||
Return on average capital employed (ROCE) (A+B) / C | 23.5 | % | 8.5 | % | ||||
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended | Six Months Ended | |||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | ||||||||||||
Net cash provided by operating activities | $ | 326,650 | $ | 273,900 | $ | 911,937 | $ | 546,660 | ||||||||
Changes in assets and liabilities | (24,768) | (77,403) | (104,188) | (69,863) | ||||||||||||
Discretionary cash flow | 301,882 | 196,497 | 807,749 | 476,797 | ||||||||||||
Capital expenditures | (225,850) | (231,014) | (421,500) | (387,271) | ||||||||||||
Investment in equity method investments | (3,303) | (27,487) | (5,131) | (62,905) | ||||||||||||
Free cash flow | $ | 72,729 | $ | (62,004) | $ | 381,118 | $ | 26,621 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Six Months Ended | ||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | |||||||||||
Net income | $ | 181,009 | $ | 42,431 | $ | 443,772 | $ | 159,662 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 14,567 | 23,328 | 26,748 | 43,386 | |||||||||||
Other expense | 143 | 118 | 287 | 232 | |||||||||||
Income tax expense | 55,086 | 12,152 | 132,957 | 51,793 | |||||||||||
Depreciation, depletion and amortization | 96,147 | 84,910 | 188,405 | 167,038 | |||||||||||
Exploration | 4,504 | 54,500 | 10,548 | 58,117 | |||||||||||
(Gain) loss on sale of assets | — | (544) | 1,500 | 40,505 | |||||||||||
Non-cash (gain) loss on derivative instruments | (48,252) | 9,487 | (3,529) | (22,221) | |||||||||||
(Earnings) loss on equity method investments | (3,650) | 4 | (7,334) | 998 | |||||||||||
Equity method investment distributions | 4,779 | — | 9,508 | — | |||||||||||
Stock-based compensation | 6,721 | 5,695 | 21,853 | 11,142 | |||||||||||
EBITDAX | $ | 311,054 | $ | 232,081 | $ | 824,715 | $ | 510,652 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | June 30, | December 31, | |||||
Total debt | $ | 1,219,555 | $ | 1,226,104 | |||
Stockholders' equity | 2,344,804 | 2,088,159 | |||||
Total capitalization | $ | 3,564,359 | $ | 3,314,263 | |||
Total debt | $ | 1,219,555 | $ | 1,226,104 | |||
Less: Cash and cash equivalents | (241,394) | (2,287) | |||||
Net debt | $ | 978,161 | $ | 1,223,817 | |||
Net debt | $ | 978,161 | $ | 1,223,817 | |||
Stockholders' equity | 2,344,804 | 2,088,159 | |||||
Total adjusted capitalization | $ | 3,322,965 | $ | 3,311,976 | |||
Total debt to total capitalization ratio | 34.2 | % | 37.0 | % | |||
Less: Impact of cash and cash equivalents | 4.8 | % | — | % | |||
Net debt to adjusted capitalization ratio | 29.4 | % | 37.0 | % |
Capital Expenditures | ||||||||||||||||
Quarter Ended | Six Months Ended | |||||||||||||||
(In thousands) | 2019 | 2018 | 2019 | 2018 | ||||||||||||
Cash paid for capital expenditures | $ | 225,850 | $ | 231,014 | $ | 421,500 | $ | 387,271 | ||||||||
Change in accrued capital costs | (5,466) | (17,308) | 3,168 | (6,275) | ||||||||||||
Exploratory dry hole cost | (3) | (51,145) | (16) | (51,085) | ||||||||||||
Capital expenditures | $ | 220,381 | $ | 162,561 | $ | 424,652 | $ | 329,911 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-reports-second-quarter-2019-results-expands-share-repurchase-program-authorization-300891520.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 25, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of nine cents ($0.09) per share on the Company's common stock. The dividend will be paid August 22, 2019 to all shareholders of record as of the close of business August 8, 2019.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300891192.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 1, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its second quarter 2019 earnings conference call on Friday, July 26th, 2019 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-second-quarter-2019-earnings-release-date-and-conference-call-300878259.html
SOURCE Cabot Oil & Gas Corporation
DENVER, June 12, 2019 /PRNewswire/ -- EnerCom has released the presentation schedule for the oil and gas companies presenting at its 24th annual The Oil & Gas Conference® on Aug. 11-14, 2019, in Denver, Colorado.
Day One Presenting Companies at the 2019 EnerCom Conference
Aug. 12, 2019, the first day of the EnerCom conference presentation schedule, features a large, established group of operators working across North America's shale basins and internationally, including:
The conference investor presentations begin at 7:30 a.m. and run through 4:30 p.m. on Monday, Aug. 12.
Expert Speakers: Global energy industry leaders, economists, market strategists, government officials, energy finance professionals and other energy experts will provide their insights on global commodities markets, energy exports, frac sand supply and logistics, and capital sources for energy development.
EnerCom is pleased to include Credit Agricole CIB's Chief Economist for the United States Michael Carey as a guest expert speaker at 11:30 a.m. on Monday, Aug. 12. Carey will provide his insight on energy markets, capital markets and market conditions going forward.
Monday's luncheon keynote address on Aug. 12, 2019 will be provided by Cedric Burgher, Occidental Petroleum (NYSE: OXY) CFO.
Online Registration is Open for EnerCom's 24TH Annual The Oil & Gas Conference®: Buyside investors and oil and gas company professionals may register for the event through the conference website registration page.
Conference Details: The Oil & Gas Conference® 24 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and to gain exposure to important energy topics affecting the global oil and gas industry.
The EnerCom conference forum fosters healthy dialogue and informal networking opportunities for attendees at several sponsored events the week of the conference.
Public and Private Company Presenters: The 2019 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2019 presenting companies will be updated on the conference website. The daily schedule of presenters is also posted on the website (presenters, days, times are subject to change).
How to Hear the Luncheon Speakers: Completing online registration well in advance of The Oil & Gas Conference® will provide your best chance to gain insight from Occidental Petroleum SVP and chief financial officer Cedric Burgher, Continental Resources Chairman and CEO Harold Hamm, and global supermajor Eni, SpA VP of North America Investor Relations Andrew Lees.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, family offices, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies may register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo. Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Haynes and Boone; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Holland & Hart; MUFG; Petrie Partners; SMBC; and Wells Fargo.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – Q1 - 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
About CIBC
CIBC is a leading Canadian-based global financial institution with a reputation as a strong, reliable banking partner focused on delivering customized products and services built on innovative thinking and leading technology.
Through our major business units – Canadian Personal & Business Banking, Canadian Commercial Banking & Wealth Management, U.S. Commercial Banking & Wealth Management and Capital Markets – our more than 45,000 employees provide a full range of financial products and services to 10 million clients around the world.
With offices throughout North America and other major financial centers, we are widely recognized as a strong global financial institution with more than $634 billion in assets and a market capitalization of $50 billion. We are rated A+ by Standard & Poor's, Aa2 by Moody's Investor Service and AA- by Fitch Ratings.
Our dedicated industry specialists based in Houston, New York, Calgary, London, Hong Kong, Beijing, Tokyo, Singapore and Sydney draw on the breadth of our capabilities to support firms across the entire energy value chain. From credit commitments, A&D advisory, M&A, and capital markets, we help our clients achieve their objectives and unlock value across a range of market conditions.
Visit www.cibccm.com/energy to learn more about CIBC Capital Markets and our energy capabilities.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests. Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group. With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Holland & Hart
Holland & Hart's oil and gas clients include the major, large independent producers and small to medium sized independents.
The Mountain West is one of the nation's leading oil and gas producing regions, and we are the only law firm with established oil and gas lawyers in every state in the region. We provide clients broad-based, in-depth industry knowledge and legal capabilities by local practitioners who have long-standing professional relationships with decision makers in each of the Mountain West states.
We assist clients at every stage of the oil and gas business, from upstream activities including exploration, production, secondary and tertiary recovery, to midstream gathering and processing activities; and to downstream elements including refining, pipelines, local distribution, marketing, and Federal and State utility regulation. Within each segment of the oil and gas business, Holland & Hart's regional team has experience providing representation every step of the way.
For details, please contact Lisa Adelberg in the Denver office: (303) 295-8148.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Wells Fargo & Company
Wells Fargo & Company (NYSE: WFC) is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
View original content:http://www.prnewswire.com/news-releases/enercom-posts-schedule-of-presenters-for-the-oil--gas-conference-aug-11-14-2019-300866065.html
SOURCE EnerCom, Inc.
DENVER, June 5, 2019 /PRNewswire/ -- EnerCom is pleased to announce that global oil and gas giant Eni, SpA Vice President Andrew Lees will deliver the keynote luncheon address at EnerCom's The Oil & Gas Conference® on Aug. 14, 2019.
Eni, SpA
Eni, SpA (NYSE: E) is an Italian global oil and gas and energy company operating in 67 countries worldwide, with 30,000 employees in upstream, midstream and downstream operations. Eni reported daily production for oil and gas of 1.85 MMBOPD for 2018. The company's adjusted operating profit for 2018 more than doubled its 2017 operating profit and represented Eni's best performance of the past eight years, Eni reports.
In 2018 Eni, SpA's upstream exploration group operated in:
Goliat has been developed using the world's largest and most sophisticated cylindrical floating production and storage unit - FPSO—it is the largest and most sophisticated cylindrical FPSO ever built with production capacity of a million barrels of oil.
"With the increasing integration of Upstream and Mid-downstream and due to the massive amount of gas we have discovered, we are turning into a gas and power company with an evolving model that is that is still tied to retail but linked to Upstream," Eni said.
Andrew Lees
Andrew Lees is vice president of North America investor relations for Eni, SpA.
Lees draws on a wealth of energy investing, analysis and oil and gas finance and capital experience in his leadership of Eni, SpA's North American investor relations duties. Before joining Eni in 2015, he was principal at Gadsden Enterprises, LLC. Lees previously served as Invesco's lead portfolio manager for both the energy team and the gold and precious metals team. He entered the investment industry in 1994 and worked for Invesco from 2005 to 2013. Before Invesco Lees served as director of investment banking with Trinity Capital Services, director and research analyst with RBC Capital Markets, VP and senior analyst for Stifel, Nicolaus & Co., senior analyst for Petrie Parkman & Co., and as a research analyst for A.G. Edwards.
How to Hear the Speakers: Completing online registration well in advance of The Oil & Gas Conference® will provide your best chance to gain insight from global supermajor Eni during Mr. Lees' luncheon as well as hearing the luncheon discussions with Continental Resources Chairman and CEO Harold Hamm and Occidental Petroleum SVP and chief financial officer Cedric Burgher earlier in the conference.
Online Registration is Open for EnerCom's 24TH Annual The Oil & Gas Conference®: The conference is August 11-14, 2019, at the Westin Denver Downtown hotel. Buyside investors and oil and gas company professionals may register for the event through the conference website.
Conference Details: The Oil & Gas Conference® 24 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and to gain exposure to important energy topics affecting the global oil and gas industry.
The EnerCom forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2019 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2019 presenting companies will be updated on the conference website.
The list of EnerCom's 2019 presenting companies includes (but is not limited to) the following companies:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials, energy finance professionals and other energy experts will provide their insights on global commodities markets, the U.S. becoming a net energy exporter, frac sand supply and logistics, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, family offices, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo.
Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Haynes and Boone; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Holland & Hart; MUFG; Petrie Partners; SMBC; and Wells Fargo.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – Q1 - 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests. Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group. With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA
joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Holland & Hart
Holland & Hart's oil and gas clients include the major, large independent producers and small to medium sized independents.
The Mountain West is one of the nation's leading oil and gas producing regions, and we are the only law firm with established oil and gas lawyers in every state in the region. We provide clients broad-based, in-depth industry knowledge and legal capabilities by local practitioners who have long-standing professional relationships with decision makers in each of the Mountain West states.
We assist clients at every stage of the oil and gas business, from upstream activities including exploration, production, secondary and tertiary recovery, to midstream gathering and processing activities; and to downstream elements including refining, pipelines, local distribution, marketing, and Federal and State utility regulation. Within each segment of the oil and gas business, Holland & Hart's regional team has experience providing representation every step of the way.
For details, please contact Lisa Adelberg in the Denver office: (303) 295-8148.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Wells Fargo & Company
Wells Fargo & Company (NYSE: WFC) is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
View original content:http://www.prnewswire.com/news-releases/eni-vp-andrew-lees-to-keynote-enercoms-the-oil--gas-conference-aug-14-2019-300862186.html
SOURCE EnerCom, Inc.
DENVER, May 29, 2019 /PRNewswire/ -- EnerCom is pleased to announce that legendary oilman Harold G. Hamm, chairman and CEO of Continental Resources (NYSE: CLR), will take the stage for a discussion about U.S. shale and look at the prospects for U.S. oil and gas exploration in a "fireside chat" Tuesday, August 13, 2019, during EnerCom's The Oil & Gas Conference® in downtown Denver's Westin hotel.
Limited space is available for conference registrants to join the discussion with Mr. Hamm. Completing online registration well in advance of The Oil & Gas Conference® will provide your best chance to participate in Mr. Hamm's luncheon discussion during the 2019 EnerCom conference.
Harold Hamm and Continental Resources
Harold Hamm is founder, chairman and chief executive officer of Continental Resources, one of North America's iconic oil and gas explorers and producers and one of the leading oil producers in the Bakken oil play in the Williston Basin and the STACK/SCOOP plays in Oklahoma. With a market capitalization of $14.5 billion, Continental ranks in the top ten largest U.S. independent exploration and production companies, sharing the top of the list with companies like ConocoPhillips ($COP), EOG Resources ($EOG) and Occidental Petroleum (NYSE: OXY), whose CFO Cedric Burgher will give a luncheon keynote address at The Oil & Gas Conference® on Monday, Aug. 12.
Mr. Hamm is heavily involved with furthering the success of the U.S. oil and gas industry on a global scale. He co-founded and serves as chairman of the Domestic Energy Producers Alliance, whose goal is to preserve the millions of jobs and billions of dollars in economic activity and tax revenues generated by onshore drilling and production activities within the United States. Through his work with DEPA, Mr. Hamm is widely recognized as the man who led the charge to lift America's 40-year-old ban on U.S. crude oil exports, opening new global markets for America's oil producers.
Hamm, the youngest of 13 children born to a family of sharecroppers, began working in the oilfields as a teenager and founded Continental Resources in 1967 at the age of 21. He is a frequent guest on business and financial cable networks and global business publications. Mr. Hamm has been recognized by numerous industry groups as Executive of the Year, Wildcatter of the Year, Chief Roughneck, CEO of the Year and Entrepreneur of the Year. In 2012 Harold Hamm was named by TIME Magazine as one of the "100 Most Influential People in the World."
Online registration is open for EnerCom's 24TH annual The Oil & Gas Conference®
The conference is August 11-14, 2019, at the Westin Denver Downtown hotel. Buyside investors and oil and gas company professionals may register for the event through the conference website.
Conference Details: The Oil & Gas Conference® 24 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and to gain exposure to important energy topics affecting the global oil and gas industry.
The EnerCom forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2019 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2019 presenting companies will be updated on the conference website.
The list of EnerCom's 2019 presenting companies includes (but is not limited to) the following companies:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials, energy finance professionals and other energy experts will provide their insights on global commodities markets, the U.S. becoming a net energy exporter, frac sand supply and logistics, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, family offices, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo.
Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Haynes and Boone; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Holland & Hart; MUFG; Petrie Partners; SMBC; and Wells Fargo.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – Q1 - 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests.
Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA
joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Holland & Hart
Holland & Hart's oil and gas clients include the major, large independent producers and small to medium sized independents.
The Mountain West is one of the nation's leading oil and gas producing regions, and we are the only law firm with established oil and gas lawyers in every state in the region. We provide clients broad-based, in-depth industry knowledge and legal capabilities by local practitioners who have long-standing professional relationships with decision makers in each of the Mountain West states.
We assist clients at every stage of the oil and gas business, from upstream activities including exploration, production, secondary and tertiary recovery, to midstream gathering and processing activities; and to downstream elements including refining, pipelines, local distribution, marketing, and Federal and State utility regulation. Within each segment of the oil and gas business, Holland & Hart's regional team has experience providing representation every step of the way.
For details, please contact Lisa Adelberg in the Denver office: (303) 295-8148.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Wells Fargo & Company
Wells Fargo & Company (NYSE: WFC) is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
View original content:http://www.prnewswire.com/news-releases/continental-petroleum-chairman-harold-hamm-to-keynote-enercoms-the-oil--gas-conference-tues-aug-13-2019-300858017.html
SOURCE EnerCom, Inc.
DENVER, May 14, 2019 /PRNewswire/ -- EnerCom, Inc. is pleased to announce that registration is open for the 24th annual edition of its popular The Oil & Gas Conference® in Denver, Colo.
This year's oil and gas investment conference will be held August 11-14, 2019, at the Westin Denver Downtown hotel. Buyside investors and oil and gas company professionals may register for the event through the conference website.
Conference Details: The Oil & Gas Conference® 24 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and to gain exposure to important energy topics affecting the global oil and gas industry.
The EnerCom forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2018 presenting companies will be updated on the conference website.
The 2019 presenting companies include but are not limited to:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials and other energy experts will provide their insights on global commodities markets, the U.S. becoming a net energy exporter, exports of crude oil and natural gas, frac sand supply and logistics, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo. Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Haynes and Boone; MUFG; Petrie Partners; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – Q1 - 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests.
Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group. With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
View original content:http://www.prnewswire.com/news-releases/registration-is-open-for-24th-annual-the-oil--gas-conference-in-denver-300849985.html
SOURCE EnerCom, Inc.
HOUSTON, April 26, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the first-quarter of 2019.
"For the quarter, Cabot generated record levels of operating cash flow, free cash flow, adjusted net income, and production, resulting from continued operational success, disciplined capital allocation and cost control, and strong price realizations," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "For the full-year, we remain on track to deliver earnings per share growth, return on capital employed, and a free cash flow yield that are extremely attractive when compared across all sectors of the market."
First-Quarter 2019 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, discretionary cash flow, EBITDAX, free cash flow, net debt to adjusted capitalization ratio, and ROCE.
First-Quarter 2019 Financial Results
First-quarter 2019 daily equivalent production was 2,276 Mmcfe per day (100 percent natural gas), exceeding the high-end of the Company's guidance range and representing a 21 percent increase relative to the first-quarter of 2018. On a divestiture-adjusted basis, first-quarter 2019 daily equivalent production increased 25 percent relative to the prior-year comparable quarter.
First-quarter 2019 net income was $262.8 million, or $0.62 per share, compared to net income of $117.2 million, or $0.26 per share, in the prior-year period. First-quarter 2019 adjusted net income (non-GAAP) was $307.8 million, or $0.73 per share, compared to adjusted net income of $128.5 million, or $0.28 per share, in the prior-year period. First-quarter 2019 EBITDAX (non-GAAP) was $513.7 million, compared to $278.6 million in the prior-year period.
First-quarter 2019 net cash provided by operating activities was $585.3 million, compared to $272.8 million in the prior-year period. First-quarter 2019 discretionary cash flow (non-GAAP) was $505.9 million, compared to $280.3 million in the prior-year period. First-quarter 2019 free cash flow (non-GAAP) was $308.4 million, compared to $88.6 million in the prior-year period.
First-quarter 2019 natural gas price realizations, including the impact of derivatives, were $3.35 per thousand cubic feet (Mcf), an increase of 37 percent compared to the prior-year period. Excluding the impact of derivatives, first-quarter 2019 natural gas price realizations were $3.09 per Mcf, representing a $0.06 discount to NYMEX settlement prices compared to a $0.50 discount in the prior-year comparable quarter. "Given our access to high seasonal demand in the Mid-Atlantic market and improving regional basis differentials, Cabot recognized its best corporate-wide differential since the second-quarter of 2013," commented Dinges.
First-quarter 2019 operating expenses (including financing) decreased to $1.48 per thousand cubic feet equivalent (Mcfe), a six percent improvement compared to the prior-year period.
Cabot incurred a total of $204.3 million of capital expenditures in the first-quarter of 2019 including $202.4 million of drilling and facilities capital, $0.6 million of leasehold acquisition capital, and $1.3 million of other capital. Additionally, the Company contributed $1.8 million to its equity method pipeline investments. See the supplemental table at the end of this press release reconciling the capital expenditures during the first-quarter of 2019.
Dividend Increase
Cabot's Board of Directors has approved a 29 percent increase in its quarterly cash dividend to $0.09 per share on the Company's common stock, resulting in the fourth dividend increase in the last two years. The dividend will be paid on May 29, 2019 to all shareholders of record as of the close of business on May 15, 2019. "Our capital allocation strategy remains focused on returning at least 50 percent of our free cash flow to shareholders annually through the combination of a growing dividend and share repurchases," highlighted Dinges. "Even when stress-testing our five-year plan to natural gas prices that are significantly below the current forward curve, Cabot's anticipated free cash flow profile would enable the Company to continue to grow its dividend over time to a yield that is competitive relative to the broader equity market."
Financial Position and Liquidity
As of March 31, 2019, Cabot had total debt of $1.2 billion and cash on hand of $314.9 million. The Company's debt-to-total capitalization ratio and debt-to-trailing twelve months EBITDAX ratio were 34.4 percent and 0.8x, respectively, compared to 37.0 percent and 1.0x as of December 31, 2018.
On April 22, 2019, the Company closed on an amended and restated unsecured revolving credit facility (the "Credit Facility") that matures in April 2024, with an additional one year extension provision. The borrowing base under the Credit Facility remained unchanged from the Company's prior revolving credit facility at $3.2 billion, while the Company elected to reduce its available commitments to $1.5 billion. The Company currently has no debt outstanding under the Credit Facility, resulting in over $1.8 billion of liquidity as of the closing of this Credit Facility.
Second-Quarter and Full-Year 2019 Guidance Update
Cabot has provided its second-quarter 2019 production guidance range of 2,300 to 2,350 Mmcfe per day. The Company has also reiterated its 2019 production growth guidance of 20 percent and its capital budget of $800 million. Additionally, the Company has updated its guidance on estimated key financial metrics for 2019 in the table below.
Estimated 2019 Key Financial Metrics (1) | $2.50 NYMEX | $2.75 NYMEX | $3.00 NYMEX | |||
Adjusted Earnings Per Share Growth (%) | 25% - 35% | 45% - 55% | 65% - 75% | |||
Free Cash Flow ($mm) | $500 - $550 | $600 - $650 | $700 - $750 | |||
Return on Capital Employed (%) | 20% - 21% | 22% - 23% | 24% - 25% |
(1) | Ranges for estimated key financial metrics based on guidance ranges for operating expenses |
For further disclosure on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast
A conference call is scheduled for Friday, April 26, 2019, at 9:30 a.m. Eastern Time to discuss first-quarter 2019 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | ||||||||
Three Months Ended | ||||||||
2019 | 2018 | |||||||
PRODUCTION VOLUMES | ||||||||
Natural gas (Bcf) | 204.8 | 164.6 | ||||||
Crude oil and condensate (Mbbl) | — | 754.0 | ||||||
Natural gas liquids (NGLs) (Mbbl) | — | 75.1 | ||||||
Equivalent production (Bcfe) | 204.8 | 169.6 | ||||||
Daily equivalent production (Mmcfe/day) | 2,276 | 1,884 | ||||||
AVERAGE SALES PRICE | ||||||||
Natural gas, including hedges ($/Mcf) | $ | 3.35 | $ | 2.44 | ||||
Natural gas, excluding hedges ($/Mcf) | $ | 3.09 | $ | 2.50 | ||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | 63.61 | ||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | 64.61 | ||||
NGL ($/Bbl) | $ | — | $ | 23.75 | ||||
AVERAGE UNIT COSTS ($/Mcfe) | ||||||||
Direct operations | $ | 0.09 | $ | 0.12 | ||||
Transportation and gathering | 0.67 | 0.66 | ||||||
Taxes other than income | 0.03 | 0.04 | ||||||
Exploration | 0.03 | 0.02 | ||||||
Depreciation, depletion and amortization | 0.45 | 0.48 | ||||||
General and administrative (excluding stock-based compensation) | 0.08 | 0.11 | ||||||
Stock-based compensation | 0.07 | 0.03 | ||||||
Interest expense | 0.06 | 0.12 | ||||||
$ | 1.48 | $ | 1.58 | |||||
WELLS DRILLED (1) | ||||||||
Gross | 25 | 15 | ||||||
Net | 25.0 | 15.0 | ||||||
WELLS COMPLETED (1) | ||||||||
Gross | 14 | 11 | ||||||
Net | 14.0 | 11.0 |
___________________________________________________________ | |
(1) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands, except per share amounts) | 2019 | 2018 | |||||
OPERATING REVENUES | |||||||
Natural gas | $ | 633,174 | $ | 412,108 | |||
Crude oil and condensate | — | 48,722 | |||||
Gain on derivative instruments | 8,257 | 5,577 | |||||
Brokered natural gas | — | 4,950 | |||||
Other | 250 | 1,870 | |||||
641,681 | 473,227 | ||||||
OPERATING EXPENSES | |||||||
Direct operations | 18,334 | 20,070 | |||||
Transportation and gathering | 137,333 | 112,125 | |||||
Brokered natural gas | — | 4,950 | |||||
Taxes other than income | 5,847 | 7,190 | |||||
Exploration | 6,044 | 3,617 | |||||
Depreciation, depletion and amortization | 92,258 | 82,128 | |||||
General and administrative (excluding stock-based compensation) | 15,958 | 18,613 | |||||
Stock-based compensation(1) | 15,132 | 5,447 | |||||
290,906 | 254,140 | ||||||
Earnings (loss) on equity method investments | 3,684 | (994) | |||||
Loss on sale of assets | (1,500) | (41,049) | |||||
INCOME FROM OPERATIONS | 352,959 | 177,044 | |||||
Interest expense, net | 12,181 | 20,058 | |||||
Other expense | 144 | 114 | |||||
Income before income taxes | 340,634 | 156,872 | |||||
Income tax expense | 77,871 | 39,641 | |||||
NET INCOME | $ | 262,763 | $ | 117,231 | |||
Earnings per share - Basic | $ | 0.62 | $ | 0.26 | |||
Weighted-average common shares outstanding | 423,116 | 459,715 |
_____________________________________________________________ | |
(1) | Includes the impact of our performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | March 31, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 680,191 | $ | 544,545 | |||
Properties and equipment, net (Successful efforts method) | 3,574,622 | 3,463,606 | |||||
Other assets | 226,734 | 190,678 | |||||
$ | 4,481,547 | $ | 4,198,829 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 240,315 | $ | 287,264 | |||
Long-term debt, net | 1,219,338 | 1,226,104 | |||||
Deferred income taxes | 546,559 | 458,597 | |||||
Other liabilities | 154,396 | 138,705 | |||||
Stockholders' equity | 2,320,939 | 2,088,159 | |||||
$ | 4,481,547 | $ | 4,198,829 | ||||
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands) | 2019 | 2018 | |||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||
Net income | $ | 262,763 | $ | 117,231 | |||
Deferred income tax expense | 88,002 | 64,287 | |||||
Loss on sale of assets | 1,500 | 41,049 | |||||
Exploratory dry hole cost | 13 | (60) | |||||
Gain on derivative instruments | (8,257) | (5,577) | |||||
Net cash received (paid) in settlement of derivative instruments | 52,980 | (26,131) | |||||
Income charges not requiring cash | 108,866 | 89,501 | |||||
Changes in assets and liabilities | 79,420 | (7,540) | |||||
Net cash provided by operating activities | 585,287 | 272,760 | |||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||
Capital expenditures | (195,650) | (156,257) | |||||
Proceeds from sale of assets | 2,346 | 646,545 | |||||
Investment in equity method investments | (1,828) | (35,418) | |||||
Net cash provided by (used in) investing activities | (195,132) | 454,870 | |||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||
Net borrowings (repayments) of debt | (7,000) | — | |||||
Treasury stock repurchases | (31,378) | (207,134) | |||||
Dividends paid | (29,605) | (27,647) | |||||
Tax withholdings on vesting of stock awards | (9,570) | (7,968) | |||||
Net cash used in financing activities | (77,553) | (242,749) | |||||
Net increase in cash and cash equivalents | $ | 312,602 | $ | 484,881 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Three Months Ended | ||||||||
(In thousands, except per share amounts) | 2019 | 2018 | ||||||
As reported - net income | $ | 262,763 | $ | 117,231 | ||||
Reversal of selected items: | ||||||||
Loss on sale of assets | 1,500 | 41,049 | ||||||
(Gain) loss on derivative instruments(1) | 44,723 | (31,708) | ||||||
Stock-based compensation expense | 15,132 | 5,447 | ||||||
Interest expense related to income tax reserves | (3,052) | — | ||||||
Tax effect on selected items | (13,313) | (3,481) | ||||||
Adjusted net income | $ | 307,753 | $ | 128,538 | ||||
As reported - earnings per share | $ | 0.62 | $ | 0.26 | ||||
Per share impact of selected items | 0.11 | 0.02 | ||||||
Adjusted earnings per share | $ | 0.73 | $ | 0.28 | ||||
Weighted-average common shares outstanding | 423,116 | 459,715 |
______________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
Twelve Months Ended March 31, | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Interest expense, net | $ | 65,324 | $ | 81,418 | ||||
Interest expense related to income tax reserves (1) | (64) | — | ||||||
Tax benefit | (15,140) | (27,393) | ||||||
After-tax interest expense, net (A) | 50,120 | 54,025 | ||||||
As reported - net income (loss) | 702,575 | 111,904 | ||||||
Adjustments to as reported - net income, net of tax | 7,753 | 172,096 | ||||||
Adjusted net income (B) | 710,328 | 284,000 | ||||||
Adjusted net income before interest expense, net (A + B) | $ | 760,448 | $ | 338,025 | ||||
Total debt - beginning of twelve month period | $ | 1,522,231 | $ | 1,520,870 | ||||
Stockholders' equity - beginning of twelve month period | 2,406,516 | 2,707,179 | ||||||
Capital employed - beginning of twelve month period | 3,928,747 | 4,228,049 | ||||||
Total debt - end of twelve month period | 1,219,338 | 1,522,231 | ||||||
Stockholders' equity - end of twelve month period | 2,320,939 | 2,406,516 | ||||||
Capital employed - end of twelve month period | 3,540,277 | 3,928,747 | ||||||
Average capital employed (C) | $ | 3,734,512 | $ | 4,078,398 | ||||
Return on average capital employed (ROCE) (A+B) / C | 20.4 | % | 8.3 | % |
______________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Three Months Ended | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Net cash provided by operating activities | $ | 585,287 | $ | 272,760 | ||||
Changes in assets and liabilities | (79,420) | 7,540 | ||||||
Discretionary cash flow | 505,867 | 280,300 | ||||||
Capital expenditures | (195,650) | (156,257) | ||||||
Investment in equity method investments | (1,828) | (35,418) | ||||||
Free cash flow | $ | 308,389 | $ | 88,625 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, cash distributions received from equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Three Months Ended | ||||||||
(In thousands) | 2019 | 2018 | ||||||
Net income | $ | 262,763 | $ | 117,231 | ||||
Plus (less): | ||||||||
Interest expense, net | 12,181 | 20,058 | ||||||
Other expense | 144 | 114 | ||||||
Income tax expense | 77,871 | 39,641 | ||||||
Depreciation, depletion and amortization | 92,258 | 82,128 | ||||||
Exploration | 6,044 | 3,617 | ||||||
Loss on sale of assets | 1,500 | 41,049 | ||||||
Non-cash (gain) loss on derivative instruments | 44,723 | (31,708) | ||||||
(Earnings) loss on equity method investments | (3,684) | 994 | ||||||
Equity method investment distributions | 4,729 | — | ||||||
Stock-based compensation | 15,132 | 5,447 | ||||||
EBITDAX | $ | 513,661 | $ | 278,571 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | March 31, | December 31, | |||||
Total debt | $ | 1,219,338 | $ | 1,226,104 | |||
Stockholders' equity | 2,320,939 | 2,088,159 | |||||
Total capitalization | $ | 3,540,277 | $ | 3,314,263 | |||
Total debt | $ | 1,219,338 | $ | 1,226,104 | |||
Less: Cash and cash equivalents | (314,889) | (2,287) | |||||
Net debt | $ | 904,449 | $ | 1,223,817 | |||
Net debt | $ | 904,449 | $ | 1,223,817 | |||
Stockholders' equity | 2,320,939 | 2,088,159 | |||||
Total adjusted capitalization | $ | 3,225,388 | $ | 3,311,976 | |||
Total debt to total capitalization ratio | 34.4 | % | 37.0 | % | |||
Less: Impact of cash and cash equivalents | 6.4 | % | — | % | |||
Net debt to adjusted capitalization ratio | 28.0 | % | 37.0 | % | |||
Capital Expenditures | |||||||
Three Months Ended | |||||||
(In thousands) | 2019 | 2018 | |||||
Cash paid for capital expenditures | $ | 195,650 | $ | 156,257 | |||
Change in accrued capital costs | 8,634 | 11,032 | |||||
Exploratory dry hole cost | (13) | 60 | |||||
Capital expenditures | $ | 204,271 | $ | 167,349 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-first-quarter-2019-results-increases-dividend-by-29-percent-300838825.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 2, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its first quarter 2019 earnings conference call on Friday, April 26th, 2019 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-first-quarter-2019-earnings-release-date-and-conference-call-300823239.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 22, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today announced the best year of its nearly three-decade public company history that provided record financial results, the culmination and in-service of several long-dated infrastructure initiatives, and continued momentum on the free cash flow front.
"In early 2018 we reaffirmed our commitment to creating long-term shareholder value through disciplined capital allocation by announcing a strategy focused on delivering debt-adjusted per share growth, generating positive free cash flow, improving corporate returns on capital employed, increasing return of capital to shareholders, and maintaining a strong balance sheet," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "I am happy to say that our 2018 program delivered on this strategy on all fronts."
Full-Year 2018 Highlights
New Records
Other Strategic Milestones
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, EBITDAX, discretionary cash flow, free cash flow, ROCE, pre-tax present value of future net cash flows (pre-tax PV–10) and net debt to adjusted capitalization ratio.
Fourth-Quarter 2018 Financial Results
Fourth-quarter 2018 daily equivalent production was 2,243 million cubic feet equivalent (Mmcfe) per day (100 percent natural gas), a 20 percent increase relative to the fourth-quarter of 2017 and an 11 percent sequential increase relative to the third-quarter of 2018. On a divestiture-adjusted basis, fourth-quarter 2018 daily equivalent production increased 26 percent relative to the prior-year comparable quarter.
Fourth-quarter 2018 net income was $275.0 million, or $0.64 per share, compared to net loss of $44.4 million, or $0.10 per share, in the prior-year period. Fourth-quarter 2018 adjusted net income (non-GAAP) was $235.8 million, or $0.55 per share, compared to adjusted net income of $59.5 million, or $0.13 per share, in the prior-year period. Fourth-quarter 2018 EBITDAX (non-GAAP) was $463.1 million, compared to $259.8 million in the prior-year period.
Fourth-quarter 2018 net cash provided by operating activities was $316.1 million, compared to $179.1 million in the prior-year period. Fourth-quarter 2018 discretionary cash flow (non-GAAP) was $492.8 million, compared to $240.1 million in the prior-year period. Fourth-quarter 2018 free cash flow (non-GAAP) was $241.4 million, compared to $28.7 million in the prior-year period. "Our free cash flow for the fourth-quarter exceeded our initial forecast of $200 million, driven by stronger than anticipated price realizations," commented Dinges.
Fourth-quarter 2018 natural gas price realizations, including the impact of derivatives, were $3.11 per Mcf, an increase of 43 percent compared to the prior-year period. Excluding the impact of derivatives, fourth-quarter 2018 natural gas price realizations were $3.22 per Mcf, representing a $0.42 discount to NYMEX settlement prices compared to a $0.78 discount in the prior-year comparable quarter.
Fourth-quarter 2018 operating expenses (including financing) decreased to $1.87 per Mcfe, a seven percent improvement compared to the prior-year period. All operating expenses per unit were in-line with the Company's guidance for the quarter except for depreciation, depletion and amortization and exploration, driven by higher amortization of undeveloped leasehold and exploratory dry hole costs associated with unsuccessful drilling results in our exploration areas. "After further evaluation of our remaining exploration prospect, we have determined that this area is unlikely to yield results that generate long-term value creation for our shareholders," noted Dinges. "As we have said through this entire evaluation process, we remain committed to deploying capital judiciously and if a project fails to generate competitive full-cycle returns, then we will not allocate additional capital to it going forward."
Cabot incurred a total of $223.0 million of capital expenditures in the fourth-quarter of 2018 including $207.6 million of drilling and facilities capital; $2.4 million of leasehold acquisition capital; and $13.0 million of other capital. Additionally, the Company contributed $4.4 million to its equity method pipeline investments in the fourth-quarter of 2018. See the supplemental table at the end of this press release reconciling the capital expenditures during the fourth-quarter of 2018.
Full-Year 2018 Financial Results
Full-year 2018 daily equivalent production was 2,014 Mmcfe per day (99 percent natural gas), a seven percent increase relative to the prior-year period. On a divestiture-adjusted basis, daily equivalent production for the full-year 2018 increased 14 percent relative to the prior-year period.
Full-year 2018 net income was $557.0 million, or $1.25 per share, compared to net income of $100.4 million, or $0.22 per share in the prior-year period. Adjusted net income (non-GAAP) was $531.2 million, or $1.19 per share, compared to adjusted net income of $244.5 million, or $0.53 per share, in the prior-year period. Full-year 2018 EBITDAX (non-GAAP) was $1.3 billion, compared to $1.1 billion in the prior-year period.
Full-year 2018 net cash provided by operating activities was $1,104.9 million, compared to $898.2 million in the prior-year period. Full-year 2018 discretionary cash flow (non-GAAP) was $1,268.4 million, compared to $976.1 million in the prior-year period. Full-year 2018 free cash flow (non-GAAP) was $296.6 million, compared to $154.5 million in the prior-year period. Full-year 2018 ROCE (non-GAAP) improved to 15.9 percent, compared to 7.3 percent in the prior-year period.
Full-year 2018 natural gas price realizations, including the impact of derivatives, were $2.54 per Mcf, an increase of 10 percent compared to the prior-year period. Excluding the impact of derivatives, full-year 2018 natural gas price realizations were $2.58 per Mcf, representing a $0.51 discount to NYMEX settlement prices.
Full-year 2018 operating expenses (including financing) decreased to $1.76 per Mcfe, a 13 percent improvement compared to the prior-year period.
Cabot incurred a total of $816.1 million of capital expenditures in 2018 including $758.9 million of drilling and facilities capital; $29.9 million of leasehold acquisition capital; and $27.3 million of other capital. Additionally, the Company contributed $77.3 million to its equity method pipeline investments in 2018. See the supplemental table at the end of this press release reconciling the capital expenditures for the year.
Capital Allocation Update
During the fourth-quarter of 2018, Cabot repurchased 11.3 million shares at a weighted-average share price of $22.92, resulting in full-year 2018 repurchases of approximately 38.5 million shares at a weighted-average share price of $23.48. Since reactivating the share repurchase program in the second-quarter of 2017, Cabot has reduced its shares outstanding by over nine percent to 423.4 million shares. "During the year, we returned approximately $1.0 billion of capital to shareholders via dividends and share repurchases, representing a total shareholder yield of over nine percent based on our current market capitalization," said Dinges. "We expect to continue to be an industry leader in shareholder yield as we execute on our strategy of returning at least 50 percent of free cash flow to shareholders annually."
Financial Position and Liquidity
As of December 31, 2018, Cabot had total debt of $1.2 billion and cash on hand of $2.3 million. During the fourth-quarter of 2018, Cabot paid off its $67.0 million tranche of 9.78% senior notes that matured on December 1, 2018. For the full-year, the Company retired $304 million of senior notes that matured in 2018, resulting in annualized interest expense savings of $21.8 million.
The Company's debt-to-total capitalization ratio and debt-to-trailing twelve months EBITDAX ratio were 37.0 percent and 1.0x, respectively, compared to 37.6 percent and 1.4x as of December 31, 2017. The Company currently has $7.0 million outstanding under the credit facility, resulting in approximately $1.8 billion of liquidity.
Year-End 2018 Proved Reserves
Cabot reported year-end proved reserves of 11.6 Tcfe, an increase of 19 percent over year-end 2017. Specific highlights from the Company's year-end reserve report include:
The table below reconciles the components driving the 2018 reserve increase:
Proved Reserves Reconciliation (in Bcfe) | |||
Balance at December 31, 2017 | 9,726 | ||
Revisions of prior estimates | 780 | ||
Extensions, discoveries and other additions | 2,244 | ||
Sales | (410) | ||
Production | (735) | ||
Balance at December 31, 2018 | 11,605 |
As of December 31, 2018, 100 percent of Cabot's year-end proved reserves were natural gas and were located in the Marcellus Shale. Approximately 64 percent of the year-end proved reserves were classified as proved developed and 36 percent were classified as proved undeveloped (PUD), including five percent of drilled and uncompleted PUDs.
Total costs incurred during 2018 were $902.7 million, which included $778.6 million for development costs, $94.3 million for exploration costs, and $29.9 million for lease acquisition costs.
The SEC price used for reporting Cabot's year-end 2018 proved reserves, which has been adjusted for basis and quality differentials, was $2.58 per Mcf for natural gas, representing an 11 percent year-over-year increase. Assuming the SEC prices, the pre-tax PV–10 (non-GAAP) of the year-end 2018 proved reserves was $8.1 billion. "Our latest year-end proved reserves disclosure further demonstrates the strong underlying economics and repeatability of our low-cost position in Northeast Pennsylvania," commented Dinges. "Our 25 percent growth in Marcellus reserves at industry-leading finding costs was accomplished with primarily only three rigs and two completion crews, highlighting the low capital intensity of this world-class asset."
Upper Marcellus Operations Update
The Company drilled and completed nine Generation 5 Upper Marcellus wells in the field during 2018. Based on the production data gathered to date, these wells on average have demonstrated an improvement over the average estimated ultimate recovery (EUR) per thousand lateral feet of 2.9 billion cubic feet (Bcf) from our earlier generation completions. "Given the limited sample size and production history, we plan to continue to allocate a small portion of our capital program annually to testing our Generation 5 completions in the Upper Marcellus in an effort to gather more production history from a larger sample of wells before updating our expected EURs; however, the long-term plan of fully-developing the Lower Marcellus before beginning full-development mode in the Upper Marcellus remains unchanged," stated Dinges. "Most importantly, our results from the 2018 wells reconfirmed what our previous Upper Marcellus results have demonstrated over the years, which is that we have two distinct, highly-economic intervals across our acreage position in Northeast Pennsylvania."
First-Quarter and Full-Year 2019 Guidance
Cabot has provided its first-quarter 2019 production guidance range of 2,250 to 2,275 Mmcfe per day. The Company has also updated its 2019 production growth guidance to 20 percent (27 percent on a debt-adjusted per share basis). This production growth is based on an updated capital budget of $800 million. Approximately $160 million of the 2019 capital budget relates to wells that are drilled and / or completed in 2019 but not placed on production until 2020. "While we continue to emphasize our focus on improving return on capital employed, generating significant free cash flow, and increasing our return of capital to shareholders, we also believe our unique, low-cost asset base in the Marcellus Shale allows us to deliver on these objectives while also continuing to invest in the disciplined, organic growth of our business to enhance long-term shareholder value, assuming market conditions warrant it," commented Dinges.
Based on a range of $2.50 and $3.00 per Mmbtu NYMEX prices for 2019, the Company has included its estimated key financial metrics for the year below. "Despite the current NYMEX strip for the year implying an outcome at the higher-end of this price range, we have highlighted that even at the low-end of the range our 2019 program can deliver financial metrics that are not only top-tier across all oil and gas companies but are also extremely competitive across the broader equity markets," noted Dinges.
Estimated Key Financial Metrics1 | $2.50 NYMEX | $2.75 NYMEX | $3.00 NYMEX |
Adjusted Earnings Per Share Growth (%) | 20% - 35% | 40% - 55% | 60% - 75% |
Free Cash Flow ($mm) | $475 - $525 | $600 - $650 | $700 - $750 |
Return on Capital Employed (%) | 19% - 21% | 21% - 23% | 24% - 26% |
(1) Ranges for estimated key financial metrics based on guidance ranges for operating expenses |
Conference Call Webcast
A conference call is scheduled for Friday, February 22, 2019, at 9:30 a.m. Eastern Time to discuss fourth-quarter and full-year 2018 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, returns to shareholders, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 206.3 | 164.4 | 729.9 | 655.6 | |||||||||||
Crude oil and condensate (Mbbl) | — | 1,238.0 | 754.0 | 4,440.9 | |||||||||||
Natural gas liquids (NGLs) (Mbbl) | — | 131.5 | 75.1 | 512.1 | |||||||||||
Equivalent production (Bcfe) | 206.3 | 172.6 | 735.0 | 685.3 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,243 | 1,876 | 2,014 | 1,878 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 3.11 | $ | 2.18 | $ | 2.54 | $ | 2.31 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 3.22 | $ | 2.15 | $ | 2.58 | $ | 2.30 | |||||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | 54.54 | $ | 63.68 | $ | 48.16 | |||||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | 54.77 | $ | 64.68 | $ | 47.81 | |||||||
NGL ($/Bbl) | $ | — | $ | 23.51 | $ | 21.51 | $ | 19.47 | |||||||
AVERAGE UNIT COSTS ($/Mcfe) | |||||||||||||||
Direct operations | $ | 0.08 | $ | 0.14 | $ | 0.09 | $ | 0.15 | |||||||
Transportation and gathering | 0.68 | 0.69 | 0.68 | 0.70 | |||||||||||
Taxes other than income | 0.03 | 0.04 | 0.03 | 0.05 | |||||||||||
Exploration | 0.22 | 0.03 | 0.15 | 0.03 | |||||||||||
Depreciation, depletion and amortization | 0.63 | 0.83 | 0.57 | 0.83 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.07 | 0.11 | 0.09 | 0.09 | |||||||||||
Stock-based compensation | 0.08 | 0.05 | 0.05 | 0.05 | |||||||||||
Interest expense | 0.08 | 0.12 | 0.10 | 0.12 | |||||||||||
$ | 1.87 | $ | 2.01 | $ | 1.76 | $ | 2.02 | ||||||||
WELLS DRILLED(1) | |||||||||||||||
Gross | 37 | 20 | 97 | 91 | |||||||||||
Net | 35.1 | 20.0 | 95.1 | 82.5 | |||||||||||
WELLS COMPLETED(1) | |||||||||||||||
Gross | 33 | 24 | 94 | 105 | |||||||||||
Net | 32.0 | 24.0 | 93.0 | 94.2 |
_______________________________________________________________________________ | |
(1) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) | 2018 | 2017 | 2018 | 2017 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 663,547 | $ | 353,989 | $ | 1,881,150 | $ | 1,506,078 | |||||||
Crude oil and condensate | — | 67,810 | 48,722 | 212,338 | |||||||||||
Gain (loss) on derivative instruments | 46,060 | (29,427) | 44,432 | 16,926 | |||||||||||
Brokered natural gas | 6,155 | 4,957 | 209,530 | 17,217 | |||||||||||
Other | 539 | 3,174 | 4,314 | 11,660 | |||||||||||
716,301 | 400,503 | 2,188,148 | 1,764,219 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 16,889 | 24,125 | 69,646 | 102,310 | |||||||||||
Transportation and gathering | 140,883 | 119,530 | 496,731 | 481,439 | |||||||||||
Brokered natural gas | 5,761 | 4,990 | 184,198 | 15,252 | |||||||||||
Taxes other than income | 7,208 | 6,925 | 22,642 | 33,487 | |||||||||||
Exploration | 45,654 | 4,903 | 113,820 | 21,526 | |||||||||||
Depreciation, depletion and amortization | 129,269 | 143,128 | 417,479 | 568,817 | |||||||||||
Impairment of oil and gas properties(1) | — | 414,256 | — | 482,811 | |||||||||||
General and administrative (excluding stock-based compensation) | 15,113 | 19,022 | 63,494 | 63,745 | |||||||||||
Stock-based compensation(2) | 15,516 | 7,863 | 33,147 | 34,041 | |||||||||||
376,293 | 744,742 | 1,401,157 | 1,803,428 | ||||||||||||
Earnings (loss) on equity method investments(3) | 2,146 | (96,500) | 1,137 | (100,486) | |||||||||||
(Gain) loss on sale of assets | (1,477) | 1,933 | (16,327) | (11,565) | |||||||||||
INCOME (LOSS) FROM OPERATIONS | 340,677 | (438,806) | 771,801 | (151,260) | |||||||||||
Interest expense, net | 15,624 | 20,410 | 73,201 | 82,130 | |||||||||||
Other expense (income) | 116 | 18 | 463 | (4,955) | |||||||||||
Income (loss) before income taxes | 324,937 | (459,234) | 698,137 | (228,435) | |||||||||||
Income tax expense (benefit)(4) | 49,893 | (414,793) | 141,094 | (328,828) | |||||||||||
NET INCOME (LOSS) | $ | 275,044 | $ | (44,441) | $ | 557,043 | $ | 100,393 | |||||||
Earnings (loss) per share - Basic | $ | 0.64 | $ | (0.10) | $ | 1.25 | $ | 0.22 | |||||||
Weighted-average common shares outstanding | 430,978 | 462,371 | 445,538 | 463,735 |
_______________________________________________________________________________ | |
(1) | Includes the impairment of our Eagle Ford Shale oil and gas properties in south Texas in the fourth quarter of 2017. |
(2) | Includes the impact of our performance share awards and restricted stock. |
(3) | Includes the $95.9 million other than temporary impairment of our investment in Constitution. |
(4) | Includes the impact of the remeasurement of our net deferred income tax liabilities based on the new corporate income tax rate associated with the Tax Act in the fourth quarter of 2017. The remeasurement resulted in an income tax benefit of $242.9 million. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | December 31, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 544,545 | $ | 764,957 | |||
Properties and equipment, net (Successful efforts method) | 3,463,606 | 3,072,204 | |||||
Assets held for sale | — | 778,855 | |||||
Other assets | 190,678 | 111,328 | |||||
$ | 4,198,829 | $ | 4,727,344 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 287,264 | $ | 630,050 | |||
Long-term debt, net (excluding current maturities) | 1,226,104 | 1,217,891 | |||||
Deferred income taxes | 458,597 | 227,030 | |||||
Liabilities held for sale | — | 15,748 | |||||
Other liabilities | 138,705 | 112,720 | |||||
Stockholders' equity | 2,088,159 | 2,523,905 | |||||
$ | 4,198,829 | $ | 4,727,344 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income (loss) | $ | 275,044 | $ | (44,441) | $ | 557,043 | $ | 100,393 | |||||||
Deferred income tax expense (benefit) | 97,804 | (410,844) | 229,603 | (321,113) | |||||||||||
Impairment of oil and gas properties | — | 414,256 | — | 482,811 | |||||||||||
(Gain) loss on sale of assets | 1,477 | (1,933) | 16,327 | 11,565 | |||||||||||
Exploratory dry hole cost | 41,316 | 978 | 97,741 | 3,820 | |||||||||||
(Gain) loss on derivative instruments | (46,060) | 29,427 | (44,432) | (16,926) | |||||||||||
Net cash received (paid) in settlement of derivative instruments | (21,277) | 4,469 | (41,631) | 8,056 | |||||||||||
Income charges not requiring cash | 144,500 | 248,231 | 453,712 | 707,496 | |||||||||||
Changes in assets and liabilities | (176,753) | (61,030) | (163,460) | (77,942) | |||||||||||
Net cash provided by operating activities | 316,051 | 179,113 | 1,104,903 | 898,160 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (246,967) | (177,745) | (894,470) | (764,558) | |||||||||||
Proceeds from sale of assets | 2,825 | 82,733 | 678,350 | 115,444 | |||||||||||
Investment in equity method investments | (4,397) | (33,657) | (77,263) | (57,039) | |||||||||||
Net cash used in investing activities | (248,539) | (128,669) | (293,383) | (706,153) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Net borrowings (repayments) of debt | (60,000) | — | (297,000) | — | |||||||||||
Treasury stock repurchases | (291,036) | (55,486) | (872,761) | (123,741) | |||||||||||
Dividends paid | (30,184) | (23,131) | (111,369) | (78,838) | |||||||||||
Tax withholding on vesting of stock awards | (82) | (2,044) | (8,150) | (7,973) | |||||||||||
Other | — | 8 | — | 50 | |||||||||||
Net cash used in financing activities | (381,302) | (80,653) | (1,289,280) | (210,502) | |||||||||||
Net decrease in cash and cash equivalents | $ | (313,790) | $ | (30,209) | $ | (477,760) | $ | (18,495) |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income (Loss) to Adjusted Net Income (Loss) and Adjusted Earnings Per Share
Adjusted Net Income (Loss) and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income (Loss) and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) | 2018 | 2017 | 2018 | 2017 | |||||||||||
As reported - net income (loss) | $ | 275,044 | $ | (44,441) | $ | 557,043 | $ | 100,393 | |||||||
Reversal of selected items: | |||||||||||||||
Impairment of oil and gas properties(1) | — | 414,256 | — | 482,811 | |||||||||||
Impairment of equity method investments(2) | — | 95,945 | — | 95,945 | |||||||||||
(Gain) loss on sale of assets | 1,477 | (1,933) | 16,327 | 11,565 | |||||||||||
(Gain) loss on derivative instruments(3) | (67,337) | 33,896 | (86,063) | (8,870) | |||||||||||
Stock-based compensation expense | 15,516 | 7,863 | 33,147 | 34,041 | |||||||||||
Severance expense | — | 21 | 28 | 3,213 | |||||||||||
OPEB curtailment | — | (67) | — | (4,917) | |||||||||||
Interest expense related to income tax reserves | (538) | — | 3,116 | — | |||||||||||
Tax effect on selected items | 11,619 | (203,211) | 7,637 | (226,787) | |||||||||||
Impact of 2017 tax reform | — | (242,875) | — | (242,875) | |||||||||||
Adjusted net income | $ | 235,781 | $ | 59,454 | $ | 531,235 | $ | 244,519 | |||||||
As reported - earnings (loss) per share | $ | 0.64 | $ | (0.10) | $ | 1.25 | $ | 0.22 | |||||||
Per share impact of selected items | (0.09) | 0.23 | (0.06) | 0.31 | |||||||||||
Adjusted earnings per share | $ | 0.55 | $ | 0.13 | $ | 1.19 | $ | 0.53 | |||||||
Weighted-average common shares outstanding | 430,978 | 462,371 | 445,538 | 463,735 |
_______________________________________________________________________________ | |
(1) | This amount represents the non-cash impairment of our Eagle Ford Shale oil and gas properties located in south Texas in the fourth quarter of 2017. |
(2) | This amount represents the non-cash other than temporary impairment of our investment in Constitution recorded in Loss on equity method investments in the Condensed Consolidated Statement of Operations. |
(3) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (loss) (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
(In thousands) | 2018 | 2017 | ||||||
Interest expense, net | $ | 73,201 | $ | 82,130 | ||||
Less: Interest expense related to income tax reserves (1) | (3,116) | — | ||||||
Tax benefit on interest expense, net | (16,004) | (30,346) | ||||||
After-tax interest expense, net (A) | 54,081 | 51,784 | ||||||
As reported - net income (loss) | 557,043 | 100,393 | ||||||
Adjustments to as reported - net income (loss), net of tax | (25,808) | 144,126 | ||||||
Adjusted net income (loss) (B) | 531,235 | 244,519 | ||||||
Adjusted net income (loss) before interest expense, net (A + B) | $ | 585,316 | $ | 296,303 | ||||
Total debt - beginning | $ | 1,521,891 | $ | 1,520,530 | ||||
Stockholders' equity - beginning | 2,523,905 | 2,567,667 | ||||||
Capital employed - beginning | 4,045,796 | 4,088,197 | ||||||
Total debt - ending | 1,226,104 | 1,521,891 | ||||||
Stockholders' equity - ending | 2,088,159 | 2,523,905 | ||||||
Capital employed - ending | 3,314,263 | 4,045,796 | ||||||
Average capital employed (C) | $ | 3,680,030 | $ | 4,066,997 | ||||
Return on average capital employed (ROCE) (A+B) / C | 15.9 | % | 7.3 | % |
_______________________________________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended | Twelve Months Ended December 31, | |||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Net cash provided by operating activities | $ | 316,051 | $ | 179,113 | $ | 1,104,903 | $ | 898,160 | ||||||||
Changes in assets and liabilities | 176,753 | 61,030 | 163,460 | 77,942 | ||||||||||||
Discretionary cash flow | 492,804 | 240,143 | 1,268,363 | 976,102 | ||||||||||||
Capital expenditures | (246,967) | (177,745) | (894,470) | (764,558) | ||||||||||||
Investment in equity method investments | (4,397) | (33,657) | (77,263) | (57,039) | ||||||||||||
Free cash flow | $ | 241,440 | $ | 28,741 | $ | 296,630 | $ | 154,505 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, earnings and loss on equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended December 31, | Twelve Months Ended December 31, | ||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | |||||||||||
Net income (loss) | $ | 275,044 | $ | (44,441) | $ | 557,043 | $ | 100,393 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 15,624 | 20,410 | 73,201 | 82,130 | |||||||||||
Other expense (income) | 116 | 18 | 463 | (4,955) | |||||||||||
Income tax expense (benefit) | 49,893 | (414,793) | 141,094 | (328,828) | |||||||||||
Depreciation, depletion and amortization | 129,269 | 143,128 | 417,479 | 568,817 | |||||||||||
Impairment of oil and gas properties | — | 414,256 | — | 482,811 | |||||||||||
Exploration | 45,654 | 4,903 | 113,820 | 21,526 | |||||||||||
(Gain) loss on sale of assets | 1,477 | (1,933) | 16,327 | 11,565 | |||||||||||
Non-cash (gain) loss on derivative instruments | (67,337) | 33,896 | (86,063) | (8,870) | |||||||||||
(Earnings) loss on equity method investments | (2,146) | 96,500 | (1,137) | 100,486 | |||||||||||
Stock-based compensation | 15,516 | 7,863 | 33,147 | 34,041 | |||||||||||
EBITDAX | $ | 463,110 | $ | 259,807 | $ | 1,265,374 | $ | 1,059,116 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Adjusted Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Adjusted Capitalization ratio.
(In thousands) | December 31, | December 31, | |||||
Current portion of long-term debt | $ | — | $ | 304,000 | |||
Long-term debt, net | 1,226,104 | 1,217,891 | |||||
Total debt | $ | 1,226,104 | $ | 1,521,891 | |||
Stockholders' equity | 2,088,159 | 2,523,905 | |||||
Total capitalization | $ | 3,314,263 | $ | 4,045,796 | |||
Total debt | $ | 1,226,104 | $ | 1,521,891 | |||
Less: Cash and cash equivalents | (2,287) | (480,047) | |||||
Net debt | $ | 1,223,817 | $ | 1,041,844 | |||
Net debt | $ | 1,223,817 | $ | 1,041,844 | |||
Stockholders' equity | 2,088,159 | 2,523,905 | |||||
Total adjusted capitalization | $ | 3,311,976 | $ | 3,565,749 | |||
Total debt to total capitalization ratio | 37.0 | % | 37.6 | % | |||
Less: Impact of cash and cash equivalents | — | % | 8.4 | % | |||
Net debt to adjusted capitalization ratio | 37.0 | % | 29.2 | % |
Capital Expenditures
Quarter Ended | Twelve Months Ended | |||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Cash paid for capital expenditures | $ | 246,967 | $ | 177,745 | $ | 894,470 | $ | 764,558 | ||||||||
Change in accrued capital costs | 17,326 | (2,309) | 19,346 | (3,516) | ||||||||||||
Exploratory dry hole cost | (41,316) | (978) | (97,741) | (3,820) | ||||||||||||
Capital expenditures | $ | 222,977 | $ | 174,458 | $ | 816,075 | $ | 757,222 |
Pre-tax Present Value of Future Net Cash Flows Calculation and Reconciliation
(In thousands) | December 31, | December 31, | |||||
Standardized Measure of Discounted Future Net Cash Flows | $ | 6,483,308 | $ | 5,010,446 | |||
Plus: Future Income Tax Expenses, discounted at 10% annual rate | 1,651,488 | 955,240 | |||||
Pre-tax Present Value of Future Net Cash Flows, discounted at 10% annual rate | $ | 8,134,796 | $ | 5,965,686 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-establishes-several-new-full-year-records-returns-1-0-billion-to-shareholders-repays-304-million-of-debt-300800200.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 29, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its fourth quarter and year-end 2018 earnings conference call on Friday, February 22nd, 2019 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-fourth-quarter-and-year-end-2018-earnings-release-date-and-conference-call-300786103.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 14, 2019 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of seven cents ($0.07) per share on the Company's common stock. The dividend will be paid February 7, 2019 to all shareholders of record as of the close of business January 24, 2019.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300777895.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 26, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the third-quarter of 2018.
Third-Quarter 2018 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, EBITDAX, discretionary cash flow, free cash flow, ROCE, and net debt to adjusted capitalization ratio.
"We returned to free cash flow generation during the third-quarter while delivering significant year-over-year growth in all financial metrics," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "We continue to execute on our strategy of delivering returns-focused growth in per share metrics, returning capital to shareholders, and improving our return on capital employed."
Third-Quarter 2018 Financial Results
Third-quarter 2018 daily equivalent production was 2,029 Mmcfe per day (100 percent natural gas), a 10 percent increase relative to the third-quarter of 2017 and a seven percent sequential increase relative to the second-quarter of 2018. On a divestiture-adjusted basis, third-quarter 2018 daily equivalent production increased 19 percent relative to the prior-year comparable quarter.
Third-quarter 2018 net income was $122.3 million, or $0.28 per share, compared to net income of $17.6 million, or $0.04 per share, in the prior-year period. Third-quarter 2018 adjusted net income (non-GAAP) was $108.9 million, or $0.25 per share, compared to adjusted net income of $32.0 million, or $0.07 per share, in the prior-year period. Third-quarter 2018 EBITDAX (non-GAAP) was $291.6 million, compared to $218.6 million in the prior-year period.
Third-quarter 2018 net cash provided by operating activities was $242.2 million, compared to $189.1 million in the prior-year period. Third-quarter 2018 discretionary cash flow (non-GAAP) was $298.8 million, compared to $207.2 million in the prior-year period. Third-quarter 2018 free cash flow (non-GAAP) was $28.6 million, compared to $4.0 million in the prior-year period.
Third-quarter 2018 natural gas price realizations, both including and excluding the impact of derivatives, were $2.36 per thousand cubic feet (Mcf), an increase of 16 percent compared to the prior-year period. Third-quarter 2018 natural gas price realizations represented a $0.54 discount to NYMEX settlement prices compared to a $0.99 discount in the prior-year comparable quarter.
Third-quarter 2018 operating expenses (including financing) decreased to $1.69 per thousand cubic feet equivalent (Mcfe), an 18 percent improvement compared to the prior-year period. All operating expense categories decreased on a per unit basis relative to last year's comparable quarter except for exploration, which increased primarily as a result of $5.3 million of exploratory dry hole costs related to the final activity in the Company's first exploratory area, for which the Company previously announced its decision to cease further activity.
Cabot incurred a total of $263.2 million of capital expenditures in the third-quarter of 2018 including $237.5 million of drilling and facilities capital; $16.1 million of leasehold acquisition capital; and $9.6 million of other capital. Additionally, the Company contributed $10.0 million to its equity method pipeline investments in the third-quarter of 2018. See the supplemental table at the end of this press release reconciling the capital expenditures during the third-quarter of 2018.
Year-To-Date 2018 Financial Results
Daily equivalent production for the nine-month period ended September 30, 2018 was 1,936 Mmcfe per day (99 percent natural gas), a three percent increase relative to the prior-year period. On a divestiture-adjusted basis, daily equivalent production for the nine-month period ended September 30, 2018 increased nine percent relative to the prior-year period.
For the nine-month period ended September 30, 2018, net income was $282.0 million, or $0.63 per share, compared to net income of $144.8 million, or $0.31 per share, for the nine-month period ended September 30, 2017. Adjusted net income (non-GAAP) was $295.3 million, or $0.66 per share, compared to adjusted net income of $185.1 million, or $0.40 per share, for the nine-month period ended September 30, 2017. EBITDAX (non-GAAP) for the nine-month period ended September 30, 2018 was $802.3 million, compared to $799.3 million for the nine-month period ended September 30, 2017.
For the nine-month period ended September 30, 2018, net cash provided by operating activities was $788.9 million, compared to $719.0 million for the nine-month period ended September 30, 2017. Discretionary cash flow (non-GAAP) for the nine-months ended September 30, 2018 was $775.6 million, compared to $736.0 million for the nine-month period ended September 30, 2017. Free cash flow (non-GAAP) was $55.2 million for the nine-month period ended September 30, 2018, compared to $125.8 million for the nine-month period ended September 30, 2017. ROCE (non-GAAP) improved to 10.8 percent for the trailing twelve months ended September 30, 2018, compared to 5.7 percent for the trailing twelve months ended September 30, 2017.
Natural gas price realizations, including the impact of derivatives, were $2.32 per Mcf for the nine-month period ended September 30, 2018, a decrease of one percent compared to the nine-month period ended September 30, 2017.
For the nine-month period ended September 30, 2018, operating expenses (including financing) decreased to $1.71 per Mcfe, a 16 percent improvement compared to the prior-year period.
Cabot incurred a total of $593.1 million of capital expenditures during the nine-month period ended September 30, 2018 including $551.4 million of drilling and facilities capital; $27.5 million of leasehold acquisition capital; and $14.2 million of other capital. Additionally, the Company contributed $72.9 million to its equity method pipeline investments during the nine-month period ended September 30, 2018.
Dividend Increase
Cabot's Board of Directors today approved a 17 percent increase in its quarterly cash dividend on common stock. Effective with the dividend payable on November 16, 2018, to holders of record as of November 7, 2018, the board declared a quarterly dividend of $0.07 per share on its common stock. "With the in-service of the Atlantic Sunrise pipeline project now in the rearview mirror, we have full confidence in the Company's ability to generate significant free cash flow in the coming years," commented Dinges. "As a result, we are increasing our dividend for the third time in the last 18 months as we continue to increase the focus of our capital allocation on returning cash to our shareholders."
Share Repurchase Program Update
During the third-quarter of 2018, Cabot repurchased 7.2 million shares at a weighted-average share price of $22.67. Subsequent to the end of the third-quarter, the Company repurchased an additional 2.8 million shares at a weighted-average share price of $23.17 under a Rule 10b5-1 plan, resulting in year-to-date repurchases through the date of this press release of approximately 30.0 million shares at a weighted-average share price of $23.66. Since reactivating the share repurchase program in the second-quarter of 2017, Cabot has reduced its shares outstanding by over seven percent to 431.2 million shares. "Our year-to-date share repurchases, in addition to our expected dividend payments for the year, will result in the Company returning over $820 million of capital to shareholders, implying a total shareholder yield of almost nine percent based on our current market capitalization," said Dinges.
Financial Position and Liquidity
As of September 30, 2018, Cabot had total debt of $1.3 billion and cash on hand of $316.1 million. During the third-quarter of 2018, Cabot paid off its $237.0 million tranche of 6.44% senior notes that matured on July 16, 2018, resulting in approximately $15.3 million of annualized interest expense savings going forward.
The Company's net debt-to-adjusted capitalization ratio and net debt-to-trailing twelve months EBITDAX ratio were 31.7 percent and 0.9x, respectively, compared to 29.2 percent and 1.0x as of December 31, 2017. The Company currently has no debt outstanding under the credit facility, resulting in over $2.1 billion of liquidity.
Fourth-Quarter and Full-Year 2018 Guidance
Cabot has reaffirmed its previously announced fourth-quarter 2018 net production guidance of 2,225 to 2,275 Mmcfe per day. The Company has also reaffirmed its previously announced 2018 daily production growth guidance range of 7 to 8 percent (12 to 13 percent on a debt-adjusted per share basis) and its full-year capital budget of $940 million. "Due to the recent improvement in the near-term outlook for NYMEX prices and basis differentials, we now expect to generate approximately $200 million of free cash flow during the fourth-quarter and approximately $250 million of free cash flow for the full-year, based on current strip prices", noted Dinges.
Preliminary 2019 Operating Plan
Cabot has provided its preliminary 2019 production growth guidance range of 20 to 25 percent (25 to 30 percent on a debt-adjusted per share basis). This production growth range is based on a capital budget of $800 million to $850 million. Based on current market indications for basis differentials at the time of this press release, Cabot expects its natural gas price realizations to average $0.30 below NYMEX for the full-year of 2019. Based on current strip prices and these differential assumptions, the Company's 2019 program is expected to deliver between $650 million and $700 million of free cash flow. "Our preliminary 2019 operating plan and capital budget can deliver greater than 60 percent growth in earnings per share, an improvement in ROCE to over 20 percent, and a free cash flow yield over seven percent based on our current market capitalization" said Dinges. "I would also highlight that our focus, first and foremost, is on maximizing returns and free cash flow with production growth simply being a result of disciplined capital allocation to high-quality assets. To the extent that our outlook for commodity prices in 2019 and beyond changes as a result of supply and demand dynamics during this coming winter heating season, we may reevaluate our plans in early 2019 to remain aligned with our strategic focus on maximizing returns and free cash flow."
Capital Allocation Strategy
Cabot plans to distribute greater than 50 percent of free cash flow to shareholders annually through a combination of dividends and share repurchases. The allocation of the remaining free cash flow will be dependent on market conditions with a focus preserving financial flexibility and increasing optionality throughout all commodity price cycles. "Given the inflection point we are reaching for free cash flow generation this year, we are excited to highlight our capital allocation plans beyond investing through the drill-bit in our high-return Marcellus Shale assets," stated Dinges. "Cabot has been at the forefront of the shift in strategy across the exploration and production sector to focusing on generating free cash flow, improving return on capital, and increasing return of capital. We believe our commitment to provide this level of payout to shareholders annually while still preserving financial flexibility to remain opportunistic through all cycles, maximizes Cabot's ability to create long-term shareholder value."
Conference Call Webcast
A conference call is scheduled for Friday, October 26, 2018, at 9:30 a.m. Eastern Time to discuss third-quarter 2018 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
PRODUCTION VOLUMES | |||||||||||||||
Natural gas (Bcf) | 186.5 | 161.2 | 523.6 | 491.2 | |||||||||||
Crude oil and condensate (Mbbl) | — | 1,268.0 | 754.0 | 3,202.8 | |||||||||||
Natural gas liquids (NGLs) (Mbbl) | — | 124.7 | 75.1 | 380.6 | |||||||||||
Equivalent production (Bcfe) | 186.5 | 169.5 | 528.6 | 512.7 | |||||||||||
Daily equivalent production (Mmcfe/day) | 2,029 | 1,843 | 1,936 | 1,878 | |||||||||||
AVERAGE SALES PRICE | |||||||||||||||
Natural gas, including hedges ($/Mcf) | $ | 2.36 | $ | 2.03 | $ | 2.32 | $ | 2.35 | |||||||
Natural gas, excluding hedges ($/Mcf) | $ | 2.36 | $ | 2.01 | $ | 2.33 | $ | 2.35 | |||||||
Crude oil and condensate, including hedges ($/Bbl) | $ | — | $ | 45.53 | $ | 63.68 | $ | 45.70 | |||||||
Crude oil and condensate, excluding hedges ($/Bbl) | $ | — | $ | 44.88 | $ | 64.68 | $ | 45.13 | |||||||
NGL ($/Bbl) | $ | — | $ | 17.04 | $ | 21.49 | $ | 18.08 | |||||||
AVERAGE UNIT COSTS ($/Mcfe) | |||||||||||||||
Direct operations | $ | 0.09 | $ | 0.15 | $ | 0.10 | $ | 0.15 | |||||||
Transportation and gathering | 0.69 | 0.70 | 0.67 | 0.71 | |||||||||||
Taxes other than income | 0.02 | 0.05 | 0.03 | 0.05 | |||||||||||
Exploration | 0.05 | 0.04 | 0.13 | 0.03 | |||||||||||
Depreciation, depletion and amortization | 0.65 | 0.86 | 0.55 | 0.83 | |||||||||||
General and administrative (excluding stock-based compensation) | 0.08 | 0.09 | 0.09 | 0.09 | |||||||||||
Stock-based compensation | 0.03 | 0.05 | 0.03 | 0.05 | |||||||||||
Interest expense | 0.08 | 0.12 | 0.11 | 0.12 | |||||||||||
$ | 1.69 | $ | 2.06 | $ | 1.71 | $ | 2.03 | ||||||||
WELLS DRILLED (1) | |||||||||||||||
Gross | 21 | 23 | 60 | 71 | |||||||||||
Net | 21.0 | 20.4 | 60.0 | 62.5 | |||||||||||
WELLS COMPLETED (1) | |||||||||||||||
Gross | 27 | 30 | 61 | 81 | |||||||||||
Net | 27.0 | 22.2 | 61.0 | 70.2 |
_____________________________________________________________ | |
(1) | Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2018 | 2017 | 2018 | 2017 | |||||||||||
OPERATING REVENUES | |||||||||||||||
Natural gas | $ | 440,835 | $ | 323,319 | $ | 1,217,603 | $ | 1,152,089 | |||||||
Crude oil and condensate | — | 56,913 | 48,722 | 144,528 | |||||||||||
Gain (loss) on derivative instruments | (3,537) | (836) | (1,628) | 46,353 | |||||||||||
Brokered natural gas | 105,849 | 3,528 | 203,375 | 12,260 | |||||||||||
Other | 2,026 | 2,492 | 3,775 | 8,486 | |||||||||||
545,173 | 385,416 | 1,471,847 | 1,363,716 | ||||||||||||
OPERATING EXPENSES | |||||||||||||||
Direct operations | 17,030 | 26,282 | 52,757 | 78,185 | |||||||||||
Transportation and gathering | 129,534 | 117,891 | 355,848 | 361,909 | |||||||||||
Brokered natural gas | 93,405 | 2,797 | 178,437 | 10,262 | |||||||||||
Taxes other than income | 2,852 | 9,194 | 15,434 | 26,562 | |||||||||||
Exploration | 10,049 | 6,466 | 68,166 | 16,623 | |||||||||||
Depreciation, depletion and amortization | 121,172 | 146,267 | 288,210 | 425,689 | |||||||||||
Impairment of oil and gas properties | — | — | — | 68,555 | |||||||||||
General and administrative (excluding stock-based compensation) | 14,235 | 15,395 | 48,382 | 44,724 | |||||||||||
Stock-based compensation(1) | 6,489 | 7,849 | 17,631 | 26,178 | |||||||||||
394,766 | 332,141 | 1,024,865 | 1,058,687 | ||||||||||||
Loss on equity method investments | (11) | (1,417) | (1,009) | (3,986) | |||||||||||
Gain (loss) on sale of assets | 25,655 | (11,872) | (14,850) | (13,498) | |||||||||||
INCOME FROM OPERATIONS | 176,051 | 39,986 | 431,123 | 287,545 | |||||||||||
Interest expense, net | 14,191 | 20,331 | 57,577 | 61,720 | |||||||||||
Other expense (income) | 115 | (5,083) | 347 | (4,974) | |||||||||||
Income before income taxes | 161,745 | 24,738 | 373,199 | 230,799 | |||||||||||
Income tax expense | 39,408 | 7,151 | 91,201 | 85,965 | |||||||||||
NET INCOME | $ | 122,337 | $ | 17,587 | $ | 281,998 | $ | 144,834 | |||||||
Earnings per share - Basic | $ | 0.28 | $ | 0.04 | $ | 0.63 | $ | 0.31 | |||||||
Weighted-average common shares outstanding | 440,772 | 462,498 | 450,445 | 464,194 |
____________________________________________________________________ | |
(1) | Includes the impact of the Company's performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | September 30, | December 31, | |||||
ASSETS | |||||||
Current assets | $ | 619,864 | $ | 764,957 | |||
Properties and equipment, net (Successful efforts method) | 3,366,237 | 3,072,204 | |||||
Assets held for sale | 6,114 | 778,855 | |||||
Other assets | 186,828 | 111,328 | |||||
$ | 4,179,043 | $ | 4,727,344 | ||||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current liabilities | $ | 366,098 | $ | 630,050 | |||
Long-term debt, net (excluding current maturities) | 1,218,848 | 1,217,891 | |||||
Deferred income taxes | 358,708 | 227,030 | |||||
Liabilities held for sale | 381 | 15,748 | |||||
Other liabilities | 140,861 | 112,720 | |||||
Stockholders' equity | 2,094,147 | 2,523,905 | |||||
$ | 4,179,043 | $ | 4,727,344 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES | |||||||||||||||
Net income | $ | 122,337 | $ | 17,587 | $ | 281,998 | $ | 144,834 | |||||||
Deferred income tax expense | 64,823 | 16,336 | 131,799 | 89,731 | |||||||||||
Impairment of oil and gas properties | — | — | — | 68,555 | |||||||||||
(Gain) loss on sale of assets | (25,655) | 11,872 | 14,850 | 13,498 | |||||||||||
Exploratory dry hole cost | 5,340 | — | 56,425 | 2,842 | |||||||||||
(Gain) loss on derivative instruments | 3,537 | 836 | 1,628 | (46,353) | |||||||||||
Net cash received (paid) in settlement of derivative instruments | (41) | 3,906 | (20,354) | 3,587 | |||||||||||
Income charges not requiring cash | 128,422 | 156,693 | 309,212 | 459,265 | |||||||||||
Changes in assets and liabilities | (56,569) | (18,130) | 13,294 | (16,912) | |||||||||||
Net cash provided by operating activities | 242,194 | 189,100 | 788,852 | 719,047 | |||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES | |||||||||||||||
Capital expenditures | (260,232) | (193,480) | (647,503) | (586,813) | |||||||||||
Proceeds from sale of assets | 28,657 | 31,236 | 675,525 | 32,711 | |||||||||||
Investment in equity method investments | (9,961) | (9,756) | (72,866) | (23,382) | |||||||||||
Net cash used in investing activities | (241,536) | (172,000) | (44,844) | (577,484) | |||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES | |||||||||||||||
Repayments of debt | (237,000) | — | (237,000) | — | |||||||||||
Treasury stock repurchases | (162,071) | — | (581,725) | (68,255) | |||||||||||
Dividends paid | (26,467) | (23,125) | (81,185) | (55,707) | |||||||||||
Tax withholdings on vesting of stock awards | (37) | (257) | (8,068) | (5,929) | |||||||||||
Other | — | 4 | — | 42 | |||||||||||
Net cash used in financing activities | (425,575) | (23,378) | (907,978) | (129,849) | |||||||||||
Net increase (decrease) in cash and cash equivalents | $ | (424,917) | $ | (6,278) | $ | (163,970) | $ | 11,714 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) | 2018 | 2017 | 2018 | 2017 | |||||||||||
As reported - net income | $ | 122,337 | $ | 17,587 | $ | 281,998 | $ | 144,834 | |||||||
Reversal of selected items: | |||||||||||||||
Impairment of oil and gas properties | — | — | — | 68,555 | |||||||||||
(Gain) loss on sale of assets | (25,655) | 11,872 | 14,850 | 13,498 | |||||||||||
(Gain) loss on derivative instruments(1) | 3,496 | 4,742 | (18,726) | (42,766) | |||||||||||
Stock-based compensation expense | 6,489 | 7,849 | 17,631 | 26,178 | |||||||||||
Severance expense | — | 3,192 | 28 | 3,192 | |||||||||||
OPEB curtailment | — | (4,850) | — | (4,850) | |||||||||||
Interest expense related to income tax reserves | (1,863) | — | 3,654 | — | |||||||||||
Tax effect on selected items | 4,127 | (8,427) | (4,104) | (23,577) | |||||||||||
Adjusted net income | $ | 108,931 | $ | 31,965 | $ | 295,331 | $ | 185,064 | |||||||
As reported - earnings per share | $ | 0.28 | $ | 0.04 | $ | 0.63 | $ | 0.31 | |||||||
Per share impact of selected items | (0.03) | 0.03 | 0.03 | 0.09 | |||||||||||
Adjusted earnings per share | $ | 0.25 | $ | 0.07 | $ | 0.66 | $ | 0.40 | |||||||
Weighted-average common shares outstanding | 440,772 | 462,498 | 450,445 | 464,194 |
________________________________________________________________ | |
(1) | This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in (gain) loss on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income, as defined by GAAP.
Twelve Months Ended September 30, | ||||||||
(In thousands) | 2018 | 2017 | ||||||
Interest expense, net | $ | 77,987 | $ | 82,236 | ||||
Less: Interest expense related to income tax reserves (1) | (3,681) | — | ||||||
Tax benefit | (20,227) | (30,386) | ||||||
After-tax interest expense, net (A) | 54,079 | 51,850 | ||||||
As reported - net income (loss) | 237,558 | (147,926) | ||||||
Adjustments to as reported - net income, net of tax | 117,228 | 338,100 | ||||||
Adjusted net income (B) | 354,786 | 190,174 | ||||||
Adjusted net income before interest expense, net (A + B) | $ | 408,865 | $ | 242,024 | ||||
Total debt - beginning of twelve month period | $ | 1,521,551 | $ | 1,520,190 | ||||
Stockholders' equity - beginning of twelve month period | 2,644,594 | 2,863,250 | ||||||
Capital employed - beginning of twelve month period | 4,166,145 | 4,383,440 | ||||||
Total debt - end of twelve month period | 1,285,848 | 1,521,551 | ||||||
Stockholders' equity - end of twelve month period | 2,094,147 | 2,644,594 | ||||||
Capital employed - end of twelve month period | 3,379,995 | 4,166,145 | ||||||
Average capital employed (C) | $ | 3,773,070 | $ | 4,274,793 | ||||
Return on average capital employed (ROCE) (A+B) / C | 10.8 | % | 5.7 | % |
_____________________________________________________ | |
(1) | Interest expense related to income tax reserves is included in the adjustments to as reported - net income, net of tax. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended | Nine Months Ended | |||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Net cash provided by operating activities | $ | 242,194 | $ | 189,100 | $ | 788,852 | $ | 719,047 | ||||||||
Changes in assets and liabilities | 56,569 | 18,130 | (13,294) | 16,912 | ||||||||||||
Discretionary cash flow | 298,763 | 207,230 | 775,558 | 735,959 | ||||||||||||
Capital expenditures | (260,232) | (193,480) | (647,503) | (586,813) | ||||||||||||
Investment in equity method investments | (9,961) | (9,756) | (72,866) | (23,382) | ||||||||||||
Free cash flow | $ | 28,570 | $ | 3,994 | $ | 55,189 | $ | 125,764 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, loss on equity method investments and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended | Nine Months Ended | ||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | |||||||||||
Net income | $ | 122,337 | $ | 17,587 | $ | 281,998 | $ | 144,834 | |||||||
Plus (less): | |||||||||||||||
Interest expense, net | 14,191 | 20,331 | 57,577 | 61,720 | |||||||||||
Other expense (income) | 115 | (5,083) | 347 | (4,974) | |||||||||||
Income tax expense | 39,408 | 7,151 | 91,201 | 85,965 | |||||||||||
Depreciation, depletion and amortization | 121,172 | 146,267 | 288,210 | 425,689 | |||||||||||
Impairment of oil and gas properties | — | — | — | 68,555 | |||||||||||
Exploration | 10,049 | 6,466 | 68,166 | 16,623 | |||||||||||
(Gain) loss on sale of assets | (25,655) | 11,872 | 14,850 | 13,498 | |||||||||||
Non-cash (gain) loss on derivative instruments | 3,496 | 4,742 | (18,726) | (42,766) | |||||||||||
Loss on equity method investments | 11 | 1,417 | 1,009 | 3,986 | |||||||||||
Stock-based compensation | 6,489 | 7,849 | 17,631 | 26,178 | |||||||||||
EBITDAX | $ | 291,613 | $ | 218,599 | $ | 802,263 | $ | 799,308 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Total Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Total Capitalization ratio.
(In thousands) | September 30, | December 31, | |||||
Current portion of long-term debt | $ | 67,000 | $ | 304,000 | |||
Long-term debt, net | 1,218,848 | 1,217,891 | |||||
Total debt | $ | 1,285,848 | $ | 1,521,891 | |||
Stockholders' equity | 2,094,147 | 2,523,905 | |||||
Total capitalization | $ | 3,379,995 | $ | 4,045,796 | |||
Total debt | $ | 1,285,848 | $ | 1,521,891 | |||
Less: Cash and cash equivalents | (316,077) | (480,047) | |||||
Net debt | $ | 969,771 | $ | 1,041,844 | |||
Net debt | $ | 969,771 | $ | 1,041,844 | |||
Stockholders' equity | 2,094,147 | 2,523,905 | |||||
Total adjusted capitalization | $ | 3,063,918 | $ | 3,565,749 | |||
Total debt to total capitalization ratio | 38.0 | % | 37.6 | % | |||
Less: Impact of cash and cash equivalents | 6.3 | % | 8.4 | % | |||
Net debt to adjusted capitalization ratio | 31.7 | % | 29.2 | % |
Capital Expenditures | ||||||||||||||||
Quarter Ended | Nine Months Ended | |||||||||||||||
(In thousands) | 2018 | 2017 | 2018 | 2017 | ||||||||||||
Cash paid for capital expenditures | $ | 260,232 | $ | 193,480 | $ | 647,503 | $ | 586,813 | ||||||||
Change in accrued capital costs | 8,296 | (18,005) | 2,020 | (1,207) | ||||||||||||
Exploratory dry hole cost | (5,340) | — | (56,425) | (2,842) | ||||||||||||
Capital expenditures | $ | 263,188 | $ | 175,475 | $ | 593,098 | $ | 582,764 |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 9, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today provided an operational update on the heels of the in-service of the Atlantic Sunrise project on October 6, 2018 and announced the execution of a binding precedent agreement for new pipeline takeaway capacity on Transco's Leidy South expansion project.
Operational Update
Due to the delay of the Atlantic Sunrise project's in-service date from the second-half of August 2018 to October 6, 2018 and a modest change in the timing of the Company's third-quarter pads being placed-on-production, Cabot preliminarily expects net production for the third-quarter of 2018 to be approximately 2,029 million cubic feet equivalent (Mmcfe) per day, representing a seven percent sequential increase in daily net production relative to the second-quarter of 2018 and a 19 percent increase relative to the prior-year comparable quarter on a divestiture-adjusted basis. Cabot's current gross operated production volumes are above 2.6 billion cubic feet (Bcf) per day, representing an increase of over 400 million cubic feet (Mmcf) per day, or 19 percent, relative to the Company's average daily gross volumes during the second-quarter of 2018. "We are excited to finally see the Atlantic Sunrise project placed in-service almost five years after the project was initially announced," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "This project will help alleviate the infrastructure bottlenecks that we have been operating through in Northeast Pennsylvania since the summer of 2013, resulting in an improvement in basis differentials and providing a significant opportunity to deliver a combination of returns-focused growth and free cash flow generation from our Marcellus Shale assets."
Natural gas price realizations for the third-quarter of 2018, both including and excluding the effect of hedges, are preliminarily expected to be $2.36 per thousand cubic feet (Mcf), representing a $0.54 discount to NYMEX settlement prices compared to a $0.99 discount during the third-quarter of 2017. "Our realized prices for the third-quarter came in higher than forecasted due to narrower basis differentials as fundamentals in the Northeast continued to improve," commented Dinges. "We anticipate a further strengthening of realized prices during this coming winter heating season driven by the in-service of Atlantic Sunrise, current storage level expectations, and seasonal demand."
Cabot has provided fourth-quarter 2018 net production guidance of 2,225 to 2,275 Mmcfe per day. The Company has also updated its 2018 daily production growth guidance range from 10 - 12 percent to 7 - 8 percent to reflect the impact of third-quarter actuals and the impact of modest changes to the anticipated timing of completions during the fourth-quarter. As a result of the revised timing of completions, the Company has also reduced its full-year capital budget by $20 million to $940 million.
New Takeaway Capacity on Leidy South Expansion Project
Cabot recently entered into a precedent agreement with Transco for 250,000 MMBtu per day of firm transportation capacity on the Leidy South expansion project. Cabot's capacity will deliver natural gas from the Zick interconnect in Susquehanna County, Pennsylvania to the River Road interconnect in Transco's Zone 6. The Company will also be participating as an equity owner through its ownership in the Meade Pipeline Company. The project is anticipated to be in-service as early as the fourth-quarter of 2021 assuming all necessary regulatory approvals are received in a timely manner. "Cabot is pleased to announce its participation as a shipper and owner on the Leidy South expansion project, which provides further visibility into the Company's ability to deliver longer-term growth at attractive netbacks," highlighted Dinges.
Third-Quarter 2018 Earnings Release Date and Conference Call
Cabot will host its third-quarter 2018 earnings conference call on Friday, October 26, 2018 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, expansion projects (including the timing thereof), legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-provides-operational-update-announces-new-takeaway-capacity-on-leidy-south-expansion-project-300727355.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Sept. 26, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its third quarter 2018 earnings conference call on Friday, October 26th, 2018 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-third-quarter-2018-earnings-release-date-and-conference-call-300719456.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Aug. 30, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced the election of Mr. Peter B. Delaney to its Board of Directors, effective immediately. The addition of Mr. Delaney to the Board will bring the total to nine directors, with eight qualifying as independent directors.
Mr. Delaney has a long and distinguished career in the energy and power industries, having retired in 2015 as the Chairman and Chief Executive Officer ("CEO") of OGE Energy Corporation, where he served in various capacities since 2002. During his 8-year tenure as Chairman and CEO, OGE Energy received numerous industry awards, among them the 2012 Utility of the Year and the 2013 Edison Award, the industry's highest honor. Mr. Delaney also served as CEO of Enogex, OGE Energy's natural gas midstream subsidiary from 2002 to 2013, and in 2013, served on the Board, as Chairman and later as interim CEO of its successor, Enable Midstream Partners, until December 2015. Prior to his career at OGE Energy, Mr. Delaney completed a 16-year Wall Street investment banking career, most recently serving as Managing Director of UBS, Inc. from 1997-2001.
Mr. Delaney also currently serves on the Board of Directors of Panhandle Oil & Gas and several private companies in unrelated industries, as well as several charitable and community organizations. Mr. Delaney has been hailed for his exemplary service to his industry and his community with several prestigious awards, including the Arthritis Foundation Tribute to Excellence (2015), the United Way Lifetime Achievement Award (2014), Energy Biz magazine's Utility CEO of the Year (2013) and the Journal Record Most Admired CEO of the Year (2012).
"We are delighted to add an individual with Pete's depth of experience in our industry and in the power industry, as well as his commitment of service to the community, to our Board. Pete's midstream and power experience is invaluable to Cabot, as is his extensive executive leadership and strategic background. We are confident that Pete will be a significant contributor to our Board and to Cabot and its shareholders in the years to come," stated Dan O. Dinges, Chairman, President and CEO.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-new-director-300704545.html
SOURCE Cabot Oil & Gas Corporation
DENVER, Aug. 1, 2018 /PRNewswire/ -- Regardless of whether your area of interest in the U.S. energy sector is the shale plays and companies drilling the U.S. basins, offshore drilling in the Gulf of Mexico, oil pipelines, LNG exports, Texas-sourced frac sand, oilfield services or new oilfield technologies, the 23rd annual EnerCom conference will deliver the best of the industry to the Denver Downtown Westin Hotel Denver Aug. 19-22, 2018.
The combined market value of the presenting public companies is more than $220 billion and the publicly-traded energy companies represent a combined enterprise value of more than $275 billion—55% higher than last year.
Several privately held E&Ps and related energy service companies will be at the conference in force as well this year, participating in a variety of panels at the conference. Conference attendees have a rare opportunity to hear from several large private operators who—unlike their publicly traded counterparts—often say nothing in public about their operations.
Among the private oil companies participating in the conference is Anschutz Exploration, a large operator with assets in the Powder River and Washakie Basins of Wyoming, the Piceance and DJ Basins of Colorado and the Unita Basin of Utah. Other private drillers include Permian producer Felix Energy, DJ Basin producer Great Western Oil & Gas, conventional Piceance gas producer Caerus Oil and Gas, and Powder River and Green River Basin operator Samson Resources II.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests. Buyside investors may request meetings on the conference website or contact EnerCom for more information at 303-296-8834.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
2018 Presenting Companies: The Oil & Gas Conference® 2018 presenting companies consist of the following:
Looking at basin and sector, the 2018 EnerCom conference presenting companies and companies participating in panels break out as follows (list is subject to change prior to the conference– please refer to The Oil & Gas Conference website for an updated schedule of presenting companies):
Exploration & Production and Other Energy Companies by Focus Area and Sector
Bakken/Three Forks
Eagle Ford
Permian Basin
Woodford & Other Mid-Continent – SCOOP/STACK
Marcellus/Utica
Niobrara
Gulf of Mexico/Offshore
Haynesville
Pinedale – Jonah Field – Uinta Basin
Enhanced Oil Recovery
Canadian E&Ps
International E&Ps
LNG Export Projects
Oilfield Service Companies
Midstream
Mineral, Royalty, Infrastructure Holders, Acquisition Companies
Private Companies – E&Ps, Midstream, Energy Data and Technology, Energy Capital, Government Energy Agencies
A work-in-progress schedule of the 2018 presenting companies is posted on the conference website and is regularly updated.
Sponsors of The Oil & Gas Conference®
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest independent energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates.
Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; SMBC; Opportune LLP; Petrie Partners; EnergyNet; McGriff, Seibels & Williams, Inc.; Energy Intelligence; and TGS.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Opportune LLP
Founded in 2005, Opportune is a leading global energy consulting firm specializing in adding value to clients across the energy industry, including upstream, midstream, downstream, power and gas, commodities trading and oilfield services.
Since we are not an audit firm, we are advocates of our clients and are not subject to the restrictions placed on other firms by regulatory bodies. Using our extensive knowledge of all sectors of the energy industry, we work with clients to provide comprehensive solutions to their operational and financial challenges.
Our practice areas include complex financial reporting, dispute resolution, enterprise risk, outsourcing, process and technology, reserve engineering and geosciences, restructuring, strategy and organization, tax, transactional due diligence and valuation. Opportune LLP is not a CPA firm.
Opportune's corporate headquarters are in Houston, Texas. The firm also has offices in Dallas, Denver, New York City, Tulsa, and the UK. For more information please call Ashley Hunt, Marketing Coordinator,
713.490.5050 and visit the web site https://opportune.com/.
About Petrie Partners, LLC
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
The firm was formed in 2011 (as Strategic Energy Advisors) by senior bankers formerly with Bank of America Merrill Lynch and Petrie Parkman & Co., an investment bank that built a reputation as a most trusted advisor to energy clients during the nearly two decades leading up to its merger into Merrill Lynch in 2006.
Through tenure with Petrie Parkman, Merrill Lynch and Bank of America Merrill Lynch, the senior members of the Petrie team bring to bear an average of more than 25 years of energy investment banking experience, including over 300 energy M&A and capital raising transactions representing over $350 billion of aggregate consideration.
For information about the firm, please visit www.petrie.com or call the firm's Denver office (303.953.6768) or the Houston office (713.659.0760).
About EnergyNet
EnergyNet is the only continuous oil and gas auction and sealed bid transaction service that facilitates the sale of producing working interests (operated and non-operated), overrides, royalties, mineral interests, and non-producing leasehold. EnergyNet is a continuous oil and gas property marketplace with due diligence and bidding available 24/7/365, where auctions and sealed bid packages close weekly. Most of the properties EnergyNet sells are located in the lower 48 United States and typically range in value from $1,000 to $100,000,000.
Details about how to buy and sell oil and gas properties using the EnergyNet online auction service are available on the website at https://www.energynet.com/.
About McGriff, Seibels & Williams, Inc.
McGriff, Seibels & Williams is one of the most progressive insurance brokerage firms in the United States, leading the way with innovative programs to protect clients' financial interests. Services include construction risk, energy and marine, surety, employee benefits and financial services. McGriff's Energy & Marine Division offers specialty services for clients with worldwide operations and potentially catastrophic exposures. Our expertise in this niche industry has made us one of the largest independent energy brokers in the U.S. and one of the top five energy brokers worldwide.
Our client base includes more than 50 electric/gas utility and merchant energy companies, several coal mining companies, and more than 70 E&P companies. It also includes the Strategic Petroleum Reserve and numerous oilfield service companies, including vessel operators, offshore drilling companies, and international marine construction companies.
We will structure and implement a domestic or foreign program for virtually any type of energy-related risk. We have more than 125 professionals in our energy division. Using alternative risk transfer and traditional insurance solutions, we determine the appropriate combination of coverage and risk assumption.
Please contact the company through the website or by calling 800 476 - 2211.
About Energy Intelligence
Energy Intelligence has been a leading independent provider of objective insight, unbiased analysis and reliable data for over 60 years. With offices in New York, London, Houston, Dubai, Moscow, Washington, Singapore and Brussels, we provide decision-makers with critically important information on issues and events affecting the global energy complex.
Our benchmark Information Services, Petroleum Intelligence Weekly, Oil Daily, Natural Gas Week, World Gas Intelligence and Energy Compass, are produced by highly experienced journalists, and our research reports and advisory services are provided by highly regarded analysts and economists.
Information on Energy Intelligence is available at the company website: https://www.energyintel.com/pages/non-subscriber.aspx
About TGS
TGS was founded in Houston in 1981 and over time built the dominant 2D multi-client data library in the Gulf of Mexico. The company expanded further into North America and West Africa and added a substantial 3D portfolio in the Gulf of Mexico.
Also in 1981, NOPEC was founded in Oslo and began building an industry-leading multi-client 2D database in the North Sea, with additional operations in Australia and the Far East. In 1997, NOPEC went public on the Oslo Stock Exchange. In 1998, the companies merged to form TGS-NOPEC Geophysical Company (TGS), creating a winning combination for investors, customers and employees. Since then, TGS has set the standard for geoscientific data around the world.
Additional information is available at the company website: http://www.tgs.com/about-tgs/company-history/ .
View original content:http://www.prnewswire.com/news-releases/90-public-and-private-oil-and-gas-company-leaders-and-experts-to-speak-at-the-23rd-annual-enercom---the-oil--gas-conference-300689920.html
SOURCE EnerCom, Inc.
HOUSTON, July 27, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second-quarter of 2018 and provided an update on its share repurchase program and its exploration program.
Second-Quarter 2018 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income, EBITDAX, discretionary cash flow, free cash flow, and net debt to adjusted capitalization ratio.
"We continued to demonstrate our commitment to returning capital to shareholders by actively repurchasing shares throughout the quarter, highlighting our belief that Cabot's current share price is below our intrinsic value," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "We generated modest sequential production growth during the quarter driven by the in-service of new infrastructure projects in June; however, we are excited about delivering significant returns-focused production growth during the second-half of the year coinciding with the anticipated in-service of the Atlantic Sunrise pipeline project in the second-half of August. Despite generating a free cash flow deficit in the second-quarter due to lower price realizations and the funding of the majority of the remaining capital associated with our equity investment in Atlantic Sunrise, we expect to return to positive free cash flow generation in the third and fourth quarters."
Share Repurchase Program Update
During the second-quarter of 2018, Cabot repurchased 11.6 million shares at a weighted-average share price of $23.54, including 1.6 million shares that were previously reported in the first-quarter 2018 earnings release. Year-to-date the Company has repurchased 20.0 million shares at a weighted-average share price of $24.09. Since reactivating the share repurchase program in the second-quarter of 2017, Cabot has reduced its shares outstanding by over five percent to 441.2 million shares.
Additionally, the Board of Directors has authorized an increase in the Company's share repurchase program by 20.0 million shares, bringing the current remaining authorization to 30.1 million shares (or approximately seven percent of its current shares outstanding). All purchases will be made in accordance with applicable securities laws from time to time in open market or private transactions, depending on market conditions, and may be discontinued at any time. Based on the closing share price on July 26, 2018, the program implies approximately $745 million of additional share repurchases. "Given our strong balance sheet and our outlook for continued free cash flow expansion, we believe we can execute on this expanded share repurchase program while continuing to reinvest in returns-focused growth in the Marcellus Shale" noted Dinges.
Exploration Program Update
During the second-quarter of 2018, Cabot recorded exploratory dry hole costs of $51.1 million associated with one of its two exploratory operating areas. Based on the data gathered to date, the Company has decided to cease capital allocation to this area. Cabot continues to test its second exploratory area and plans to provide an update on this area on the third-quarter 2018 earnings call. "Since we announced our plans to test two exploratory areas in April 2017, we have stressed that there is an exceptionally high hurdle internally for capital allocation given the best-in-class economics from our Marcellus Shale assets," commented Dinges. "We remain committed to being disciplined with our capital allocation and if new projects fail to generate competitive full-cycle returns, then we will not allocate additional capital to them going forward."
Second-Quarter 2018 Financial Results
Second-quarter 2018 daily equivalent production was 1,895 Mmcfe per day (100 percent natural gas), a sequential increase of four percent relative to the first-quarter of 2018 when adjusting for the Eagle Ford Shale divestiture that closed in February 2018.
Second-quarter 2018 net income was $42.4 million, or $0.09 per share, compared to net income of $21.5 million, or $0.05 per share, in the prior-year period. Second-quarter 2018 adjusted net income (non-GAAP) was $57.9 million, or $0.13 per share, compared to adjusted net income of $64.0 million, or $0.14 per share, in the prior-year period. Second-quarter 2018 EBITDAX (non-GAAP) was $232.1 million, compared to $274.4 million in the prior-year period.
Second-quarter 2018 net cash provided by operating activities was $273.9 million, compared to $260.6 million in the prior-year period. Second-quarter 2018 discretionary cash flow (non-GAAP) was $196.5 million, compared to $255.7 million in the prior-year period.
Second-quarter 2018 natural gas price realizations, including the impact of derivatives, were $2.15 per thousand cubic feet (Mcf), a decrease of 10 percent compared to the prior-year period. Excluding the impact of derivatives, second-quarter 2018 natural gas price realizations were $2.11 per Mcf, representing a $0.68 discount to NYMEX settlement prices compared to a $0.80 discount in the prior-year comparable quarter.
Second-quarter 2018 operating expenses (including financing) decreased to $1.85 per thousand cubic feet equivalent (Mcfe), an eight percent improvement compared to the prior-year period. Excluding the impact of exploratory dry hole costs associated with one of Cabot's exploration areas and non-cash interest expense related to income tax reserves, the Company's operating expenses per Mcfe improved by 24 percent compared to the prior-year period and four percent sequentially compared to the first-quarter of 2018.
Cabot incurred a total of $162.6 million of capital expenditures in the second-quarter of 2018 including $155.7 million of drilling and facilities capital; $4.0 million of leasehold acquisition capital; and $2.9 million of other capital. Additionally, the Company contributed $27.5 million to its equity method pipeline investments in the second-quarter of 2018. See the supplemental table at the end of this press release reconciling the capital expenditures during the second-quarter of 2018.
Year-To-Date 2018 Financial Results
Daily equivalent production for the six-month period ended June 30, 2018 was 1,890 Mmcfe per day (99 percent natural gas).
For the six-month period ended June 30, 2018, net income was $159.7 million, or $0.35 per share, compared to net income of $127.2 million, or $0.27 per share, for the six-month period ended June 30, 2017. Adjusted net income (non-GAAP) was $186.4 million, or $0.41 per share, compared to adjusted net income of $153.1 million, or $0.33 per share, for the six-month period ended June 30, 2017. EBITDAX (non-GAAP) for the six-month period ended June 30, 2018 was $510.7 million, compared to $580.7 million for the six-month period ended June 30, 2017.
For the six-month period ended June 30, 2018, net cash provided by operating activities was $546.7 million, compared to $529.9 million for the six-month period ended June 30, 2017. Discretionary cash flow (non-GAAP) for the six-months ended June 30, 2018 was $476.8 million, compared to $528.7 million for the six-month period ended June 30, 2017.
Natural gas price realizations, including the impact of derivatives, were $2.29 per Mcf for the six-month period ended June 30, 2018, a decrease of nine percent compared to the six-month period ended June 30, 2017.
For the six-month period ended June 30, 2018, operating expenses (including financing) decreased to $1.72 per Mcfe, a 14 percent improvement compared to the prior-year period. Excluding the impact of exploratory dry hole costs associated with one of Cabot's exploration areas and non-cash interest expense related to income tax reserves, the Company's operating expenses per Mcfe improved by 23 percent compared to the prior-year period.
Cabot incurred a total of $329.9 million of capital expenditures during the six-month period ended June 30, 2018 including $313.9 million of drilling and facilities capital; $11.3 million of leasehold acquisition capital; and $4.7 million of other capital. Additionally, the Company contributed $62.9 million to its equity method pipeline investments during the six-month period ended June 30, 2018.
Marcellus Shale Operational Highlights
During the second-quarter of 2018, the Company averaged 1,891 million cubic feet (Mmcf) per day of net Marcellus production, an increase of four percent sequentially compared to the first-quarter of 2018. During the third-quarter of 2018, the Company plans to place 37.0 net wells on production in conjunction with the anticipated in-service of the Atlantic Sunrise pipeline project during the second-half of August 2018.
Cabot is currently operating three rigs and two completion crews in the Marcellus Shale.
Financial Position and Liquidity
As of June 30, 2018, Cabot had total debt of $1.5 billion and cash on hand of $741.0 million. The Company's net debt-to-adjusted capitalization ratio and net debt-to-trailing twelve months EBITDAX ratio were 26.6 percent and 0.8x, respectively, compared to 29.2 percent and 1.0x as of December 31, 2017. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.4 billion of liquidity.
Closing of Haynesville Shale Divestiture
Subsequent to the end of the second-quarter, the Company closed on the previously announced sale of its oil and gas properties in the Haynesville Shale for net proceeds of $29.2 million, which included a $5.0 million deposit that was received in the fourth-quarter of 2017. These properties accounted for approximately 3.0 Mmcfe per day (95 percent natural gas) of net production during the second-quarter of 2018.
Third-Quarter and Full-Year 2018 Guidance Update
Cabot has provided third-quarter 2018 net production guidance of 2,100 to 2,200 Mmcfe per day. The Company has also updated its 2018 daily production growth guidance range from 10 - 15 percent to 10 - 12 percent and increased its full-year capital budget by $10 million to $960 million to reflect additional spending associated with its equity ownership in the Atlantic Sunrise pipeline project. "Due to our year-to-date actual volumes being slightly lower than originally budgeted, primarily resulting from delays in third-party compressor stations in the first-quarter and downtime on Transco and Millennium during the second-quarter, we have lowered the midpoint of our annual production growth guidance range by 1.5 percent," said Dinges. "However, we still anticipate that our 2018 exit production rate in the Marcellus will be approximately 35 percent higher than the 2017 exit rate."
For further disclosure on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast
A conference call is scheduled for Friday, July 27, 2018, at 9:30 a.m. Eastern Time to discuss second-quarter 2018 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2018 |
2017 |
2018 |
2017 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
172.4 |
166.2 |
337.0 |
330.0 |
|||||||||||
Crude oil and condensate (Mbbl) |
— |
1,014.0 |
754.0 |
1,934.6 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
— |
132.4 |
75.1 |
255.9 |
|||||||||||
Equivalent production (Bcfe) |
172.4 |
173.1 |
342.0 |
343.1 |
|||||||||||
Daily equivalent production (Mmcfe/day) |
1,895 |
1,902 |
1,890 |
1,896 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.15 |
$ |
2.38 |
$ |
2.29 |
$ |
2.51 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.11 |
$ |
2.38 |
$ |
2.30 |
$ |
2.51 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
— |
$ |
44.96 |
$ |
63.68 |
$ |
45.80 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
— |
$ |
44.03 |
$ |
64.68 |
$ |
45.29 |
|||||||
NGL ($/Bbl) |
$ |
— |
$ |
16.59 |
$ |
21.49 |
$ |
18.58 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.09 |
$ |
0.16 |
$ |
0.10 |
$ |
0.15 |
|||||||
Transportation and gathering |
0.66 |
0.70 |
0.66 |
0.71 |
|||||||||||
Taxes other than income |
0.03 |
0.05 |
0.04 |
0.05 |
|||||||||||
Exploration |
0.32 |
0.02 |
0.17 |
0.03 |
|||||||||||
Depreciation, depletion and amortization |
0.49 |
0.83 |
0.49 |
0.81 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.09 |
0.08 |
0.10 |
0.09 |
|||||||||||
Stock-based compensation |
0.03 |
0.06 |
0.03 |
0.05 |
|||||||||||
Interest expense |
0.14 |
0.12 |
0.13 |
0.12 |
|||||||||||
$ |
1.85 |
$ |
2.02 |
$ |
1.72 |
$ |
2.01 |
||||||||
WELLS DRILLED (1) |
|||||||||||||||
Gross |
24 |
27 |
39 |
48 |
|||||||||||
Net |
24.0 |
21.1 |
39.0 |
42.1 |
|||||||||||
WELLS COMPLETED (1) |
|||||||||||||||
Gross |
23 |
26 |
34 |
51 |
|||||||||||
Net |
23.0 |
24.0 |
34.0 |
48.0 |
|||||||||||
(1) Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) |
2018 |
2017 |
2018 |
2017 | |||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
364,660 |
$ |
395,328 |
$ |
776,768 |
$ |
828,770 |
|||||||
Crude oil and condensate |
— |
44,625 |
48,722 |
87,616 |
|||||||||||
Gain (loss) on derivative instruments |
(3,668) |
13,805 |
1,909 |
47,190 |
|||||||||||
Brokered natural gas |
92,576 |
4,037 |
97,526 |
8,732 |
|||||||||||
Other |
(121) |
2,662 |
1,749 |
5,994 |
|||||||||||
453,447 |
460,457 |
926,674 |
978,302 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
15,657 |
27,262 |
35,727 |
51,903 |
|||||||||||
Transportation and gathering |
114,189 |
120,544 |
226,314 |
244,018 |
|||||||||||
Brokered natural gas |
80,082 |
3,419 |
85,032 |
7,465 |
|||||||||||
Taxes other than income |
5,392 |
8,310 |
12,582 |
17,368 |
|||||||||||
Exploration |
54,500 |
3,959 |
58,117 |
10,157 |
|||||||||||
Depreciation, depletion and amortization |
84,910 |
144,322 |
167,038 |
279,422 |
|||||||||||
Impairment of oil and gas properties and other assets |
— |
68,555 |
— |
68,555 |
|||||||||||
General and administrative (excluding stock-based compensation) |
15,533 |
13,882 |
34,146 |
29,331 |
|||||||||||
Stock-based compensation(1) |
5,695 |
10,075 |
11,142 |
18,328 |
|||||||||||
375,958 |
400,328 |
630,098 |
726,547 |
||||||||||||
Loss on equity method investments |
(4) |
(1,286) |
(998) |
(2,569) |
|||||||||||
Gain (loss) on sale of assets |
544 |
(1,403) |
(40,505) |
(1,626) |
|||||||||||
INCOME FROM OPERATIONS |
78,029 |
57,440 |
255,073 |
247,560 |
|||||||||||
Interest expense, net |
23,328 |
20,619 |
43,386 |
41,390 |
|||||||||||
Other (income) expense |
118 |
(315) |
232 |
109 |
|||||||||||
Income before income taxes |
54,583 |
37,136 |
211,455 |
206,061 |
|||||||||||
Income tax expense |
12,152 |
15,609 |
51,793 |
78,814 |
|||||||||||
NET INCOME |
$ |
42,431 |
$ |
21,527 |
$ |
159,662 |
$ |
127,247 |
|||||||
Earnings per share - Basic |
$ |
0.09 |
$ |
0.05 |
$ |
0.35 |
$ |
0.27 |
|||||||
Weighted-average common shares outstanding |
451,055 |
464,768 |
455,361 |
465,057 |
|||||||||||
(1) Includes the impact of the Company's performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
June 30, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
987,413 |
$ |
764,957 |
|||
Properties and equipment, net (Successful efforts method) |
3,225,493 |
3,072,204 |
|||||
Assets held for sale |
6,828 |
778,855 |
|||||
Other assets |
176,976 |
111,328 |
|||||
$ |
4,396,710 |
$ |
4,727,344 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
590,744 |
$ |
630,050 |
|||
Long-term debt, net (excluding current maturities) |
1,218,572 |
1,217,891 |
|||||
Deferred income taxes |
293,927 |
227,030 |
|||||
Liabilities held for sale |
1,867 |
15,748 |
|||||
Other liabilities |
137,426 |
112,720 |
|||||
Stockholders' equity |
2,154,174 |
2,523,905 |
|||||
$ |
4,396,710 |
$ |
4,727,344 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands) |
2018 |
2017 |
2018 |
2017 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income |
$ |
42,431 |
$ |
21,527 |
$ |
159,662 |
$ |
127,247 |
|||||||
Deferred income tax expense |
2,689 |
20,104 |
66,976 |
73,394 |
|||||||||||
Impairment of oil and gas properties and other assets |
— |
68,555 |
— |
68,555 |
|||||||||||
(Gain) loss on sale of assets |
(544) |
1,403 |
40,505 |
1,626 |
|||||||||||
Exploratory dry hole cost |
51,145 |
— |
51,085 |
2,842 |
|||||||||||
(Gain) loss on derivative instruments |
3,668 |
(13,805) |
(1,909) |
(47,190) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
5,819 |
1,204 |
(20,312) |
(319) |
|||||||||||
Income charges not requiring cash |
91,289 |
156,719 |
180,790 |
302,573 |
|||||||||||
Changes in assets and liabilities |
77,403 |
4,861 |
69,863 |
1,218 |
|||||||||||
Net cash provided by operating activities |
273,900 |
260,568 |
546,660 |
529,946 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(231,014) |
(184,949) |
(387,271) |
(393,333) |
|||||||||||
Proceeds from sale of assets |
323 |
1,101 |
646,868 |
1,475 |
|||||||||||
Investment in equity method investments |
(27,487) |
(5,884) |
(62,905) |
(13,626) |
|||||||||||
Net cash provided by (used in) investing activities |
(258,178) |
(189,732) |
196,692 |
(405,484) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Treasury stock repurchases |
(212,520) |
(68,255) |
(419,654) |
(68,255) |
|||||||||||
Dividends paid |
(27,071) |
(23,276) |
(54,718) |
(32,582) |
|||||||||||
Tax withholdings on vesting of stock awards |
(65) |
(258) |
(8,033) |
(5,672) |
|||||||||||
Other |
— |
2 |
— |
39 |
|||||||||||
Net cash used in financing activities |
(239,656) |
(91,787) |
(482,405) |
(106,470) |
|||||||||||
Net increase (decrease) in cash and cash equivalents |
$ |
(223,934) |
$ |
(20,951) |
$ |
260,947 |
$ |
17,992 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) |
2018 |
2017 |
2018 |
2017 | |||||||||||
As reported - net income |
$ |
42,431 |
$ |
21,527 |
$ |
159,662 |
$ |
127,247 |
|||||||
Reversal of selected items: |
|||||||||||||||
Impairment of oil and gas properties and other assets |
— |
68,555 |
— |
68,555 |
|||||||||||
(Gain) loss on sale of assets |
(544) |
1,403 |
40,505 |
1,626 |
|||||||||||
(Gain) loss on derivative instruments(1) |
9,487 |
(12,601) |
(22,221) |
(47,509) |
|||||||||||
Stock-based compensation expense |
5,695 |
10,075 |
11,142 |
18,328 |
|||||||||||
Severance expense |
28 |
— |
28 |
— |
|||||||||||
Interest expense related to income tax reserves |
5,517 |
— |
5,517 |
— |
|||||||||||
Tax effect on selected items |
(4,751) |
(24,916) |
(8,232) |
(15,150) |
|||||||||||
Adjusted net income |
$ |
57,863 |
$ |
64,043 |
$ |
186,401 |
$ |
153,097 |
|||||||
As reported - earnings per share |
$ |
0.09 |
$ |
0.05 |
$ |
0.35 |
$ |
0.27 |
|||||||
Per share impact of selected items |
0.04 |
0.09 |
0.06 |
0.06 |
|||||||||||
Adjusted earnings per share |
$ |
0.13 |
$ |
0.14 |
$ |
0.41 |
$ |
0.33 |
|||||||
Weighted-average common shares outstanding |
451,055 |
464,768 |
455,361 |
465,057 |
|||||||||||
(1) This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in (gain) loss on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended |
Six Months Ended | |||||||||||||||
(In thousands) |
2018 |
2017 |
2018 |
2017 | ||||||||||||
Net cash provided by operating activities |
$ |
273,900 |
$ |
260,568 |
$ |
546,660 |
$ |
529,946 |
||||||||
Changes in assets and liabilities |
(77,403) |
(4,861) |
(69,863) |
(1,218) |
||||||||||||
Discretionary cash flow |
196,497 |
255,707 |
476,797 |
528,728 |
||||||||||||
Capital expenditures |
(231,014) |
(184,949) |
(387,271) |
(393,333) |
||||||||||||
Investment in equity method investments |
(27,487) |
(5,884) |
(62,905) |
(13,626) |
||||||||||||
Free cash flow |
$ |
(62,004) |
$ |
64,874 |
$ |
26,621 |
$ |
121,769 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, loss on equity method investments and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands) |
2018 |
2017 |
2018 |
2017 | |||||||||||
Net income |
$ |
42,431 |
$ |
21,527 |
$ |
159,662 |
$ |
127,247 |
|||||||
Plus (less): |
|||||||||||||||
Interest expense, net |
23,328 |
20,619 |
43,386 |
41,390 |
|||||||||||
Other (income) expense |
118 |
(315) |
232 |
109 |
|||||||||||
Income tax expense |
12,152 |
15,609 |
51,793 |
78,814 |
|||||||||||
Depreciation, depletion and amortization |
84,910 |
144,322 |
167,038 |
279,422 |
|||||||||||
Impairment of oil and gas properties and other assets |
— |
68,555 |
— |
68,555 |
|||||||||||
Exploration |
54,500 |
3,959 |
58,117 |
10,157 |
|||||||||||
(Gain) loss on sale of assets |
(544) |
1,403 |
40,505 |
1,626 |
|||||||||||
Non-cash (gain) loss on derivative instruments |
9,487 |
(12,601) |
(22,221) |
(47,509) |
|||||||||||
Loss on equity method investments |
4 |
1,286 |
998 |
2,569 |
|||||||||||
Stock-based compensation |
5,695 |
10,075 |
11,142 |
18,328 |
|||||||||||
EBITDAX |
$ |
232,081 |
$ |
274,439 |
$ |
510,652 |
$ |
580,708 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Total Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Total Capitalization ratio.
(In thousands) |
June 30, |
December 31, | |||||
Current portion of long-term debt |
$ |
304,000 |
$ |
304,000 |
|||
Long-term debt, net |
1,218,572 |
1,217,891 |
|||||
Total debt |
$ |
1,522,572 |
$ |
1,521,891 |
|||
Stockholders' equity |
2,154,174 |
2,523,905 |
|||||
Total capitalization |
$ |
3,676,746 |
$ |
4,045,796 |
|||
Total debt |
$ |
1,522,572 |
$ |
1,521,891 |
|||
Less: Cash and cash equivalents |
(740,994) |
(480,047) |
|||||
Net debt |
$ |
781,578 |
$ |
1,041,844 |
|||
Net debt |
$ |
781,578 |
$ |
1,041,844 |
|||
Stockholders' equity |
2,154,174 |
2,523,905 |
|||||
Total adjusted capitalization |
$ |
2,935,752 |
$ |
3,565,749 |
|||
Total debt to total capitalization ratio |
41.4 |
% |
37.6 |
% | |||
Less: Impact of cash and cash equivalents |
14.8 |
% |
8.4 |
% | |||
Net debt to adjusted capitalization ratio |
26.6 |
% |
29.2 |
% |
Capital Expenditures | ||||||||||||||||
Quarter Ended |
Six Months Ended | |||||||||||||||
(In thousands) |
2018 |
2017 |
2018 |
2017 | ||||||||||||
Cash paid for capital expenditures |
$ |
231,014 |
$ |
184,949 |
$ |
387,271 |
$ |
393,333 |
||||||||
Change in accrued capital costs |
(17,308) |
10,103 |
(6,275) |
16,798 |
||||||||||||
Exploratory dry hole cost |
(51,145) |
— |
(51,085) |
(2,842) |
||||||||||||
Capital expenditures |
$ |
162,561 |
$ |
195,052 |
$ |
329,911 |
$ |
407,289 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-second-quarter-2018-results-expands-share-repurchase-program-authorization-300687604.html
SOURCE Cabot Oil & Gas Corporation
The Oil & Gas Conference® 2018 presenting companies:
- 40 North American shale E&Ps
- 7 international E&Ps
- 10 other producers
- 9 oilfield service providers
- 9 private E&Ps, midstream and data providers
- $202 billion in market value
- 3.2 million barrels of oil equivalent production per day
- $251 billion in enterprise value
DENVER, July 12, 2018 /PRNewswire/ -- An impressive roster of publicly traded oil and gas company senior leadership teams will be telling their companies' stories and presenting operational and financial updates to investors at the 2018 edition of EnerCom's The Oil & Gas Conference®.
CEOs across the upstream and oilfield service spectrum will be at the Denver Downtown Westin Hotel Aug. 20-23, 2018 to make financial presentations and meet with buyside investors and analysts for the 2018 EnerCom conference.
Market Cap: The presenting North American shale E&Ps, other explorers and producers, international E&Ps, and global oilfield service companies represent a combined market value of $202 billion, 71% higher than last year.
Enterprise Value: The 2018 presenting companies represent a combined enterprise value of $251 billion—53% higher than last year.
Production: EnerCom conference E&Ps are producing more than 3.2 million barrels of oil per day, slightly more than last year.
As to basin and sector, the 2018 EnerCom conference presenting companies break out as follows (list is subject to change prior to conference– please refer to The Oil & Gas Conference website for an updated schedule of presenting companies):
Exploration & Production Companies by Focus Area
Bakken/Three Forks
Eagle Ford
Permian Basin
Woodford & Other Mid-Continent – SCOOP/STACK
Marcellus/Utica
Niobrara
Gulf of Mexico/Offshore
Haynesville
Pinedale – Jonah Field – Uinta Basin
Enhanced Oil Recovery
Canadian E&Ps
International E&Ps
Oilfield Service Companies
Mineral, Royalty, Infrastructure Holders
Private Companies – E&Ps, Midstream, Energy Data and Technology Providers
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America, Europe, and Australasia.
A work-in-progress schedule of the 2018 presenting companies is posted on the conference website and will be regularly updated.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests. Buyside investors may request meetings on the conference website or contact EnerCom for more information at 303-296-8834.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; SMBC; and Opportune LLP.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Opportune LLP
Founded in 2005, Opportune is a leading global energy consulting firm specializing in adding value to clients across the energy industry, including upstream, midstream, downstream, power and gas, commodities trading and oilfield services.
Since we are not an audit firm, we are advocates of our clients and are not subject to the restrictions placed on other firms by regulatory bodies. Using our extensive knowledge of all sectors of the energy industry, we work with clients to provide comprehensive solutions to their operational and financial challenges.
Our practice areas include complex financial reporting, dispute resolution, enterprise risk, outsourcing, process and technology, reserve engineering and geosciences, restructuring, strategy and organization, tax, transactional due diligence and valuation. Opportune LLP is not a CPA firm.
Opportune's corporate headquarters are in Houston, Texas. The firm also has offices in Dallas, Denver, New York City, Tulsa, and the UK. For more information please call Ashley Hunt, Marketing Coordinator, 713.490.5050, and visit the web site https://opportune.com/.
View original content:http://www.prnewswire.com/news-releases/251-billion-in-public-oil--gas-companies-will-be-in-denver-for-the-23rd-annual-enercom-conference-300680266.html
SOURCE EnerCom, Inc.
DENVER, June 20, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of oil and gas companies and energy sector experts who will be presenters at the 23rd annual edition of The Oil & Gas Conference®, coming August 19-22, 2018, to the Westin Denver Downtown.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE. We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
CONTACT: 303-296-8834
View original content:http://www.prnewswire.com/news-releases/enercom-announces-presenting-companies-for-the-oil--gas-conference-23-300669633.html
SOURCE EnerCom, Inc.
DENVER, June 13, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of oil and gas companies and energy sector experts who will be presenters at the 23rd annual edition of The Oil & Gas Conference®, coming August 19-22, 2018, to the Westin Denver Downtown.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
View original content:http://www.prnewswire.com/news-releases/enercom-updates-list-of-presenters-for-the-oil--gas-conference-23-300665469.html
SOURCE EnerCom, Inc.
DENVER, June 5, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of presenting oil and gas companies for the 23rd annual edition of The Oil & Gas Conference®, coming August 19-22, 2018, at the Westin Denver Downtown. Investment and oil and gas professionals may register for the event now through the conference website.
Conference Details: The Oil & Gas Conference® 23 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and learn about important energy topics affecting the global oil and gas industry. The forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials and other energy experts will provide their insights on topics such as global commodities markets, the U.S. becoming a net energy exporter, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Q1 - 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group ( NYSE : SMFG ) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
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SOURCE EnerCom, Inc.
DENVER, May 23, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of presenting oil and gas companies for the 23rd annual edition of its popular The Oil & Gas Conference®, coming this August to Denver, Colo.
This year's oil and gas investment conference will be held August 19-22, 2018, at the Westin Denver Downtown. Investment and oil and gas professionals may register for the event through the conference website.
Conference Details: The Oil & Gas Conference® 23 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and learn about important energy topics affecting the global oil and gas industry. The forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials and other energy experts will provide their insights on topics such as global commodities markets, the U.S. becoming a net energy exporter, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Q1 - 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA
joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Wells Fargo & Company
Wells Fargo & Company is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
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SOURCE EnerCom, Inc.
HOUSTON, May 2, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of six cents ($0.06) per share on the Company's common stock. The dividend will be paid May 30, 2018 to all shareholders of record as of the close of business May 16, 2018.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300641470.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 27, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the first-quarter of 2018.
First-Quarter 2018 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income (loss), EBITDAX, discretionary cash flow, free cash flow, and net debt to adjusted capitalization ratio.
"Our free cash flow generation and return of capital to shareholders during the quarter highlights Cabot's commitment to executing on our differentiated corporate strategy," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "With the majority of construction work already completed on our new infrastructure projects that are slated to be placed in-service beginning in the second quarter, we are excited about delivering on our combination of top-tier growth, returns and free cash flow over the coming years."
First-Quarter 2018 Financial Results
First-quarter 2018 equivalent production was 169.6 billion cubic feet equivalent (Bcfe), consisting of 164.6 billion cubic feet (Bcf) of natural gas, 754.0 thousand barrels (Mbbls) of crude oil and condensate, and 75.1 Mbbls of natural gas liquids (NGLs). Production for all three product categories exceeded the high-end of the Company's guidance for the quarter.
First-quarter 2018 net income was $117.2 million, or $0.26 per share, compared to net income of $105.7 million, or $0.23 per share, in the prior-year period. First-quarter 2018 adjusted net income (non-GAAP) was $128.5 million, or $0.28 per share, compared to adjusted net income of $89.1 million, or $0.19 per share, in the prior-year period. First-quarter 2018 EBITDAX (non-GAAP) was $278.6 million, compared to $306.3 million in the prior-year period.
First-quarter 2018 net cash provided by operating activities was $272.8 million, compared to $269.4 million in the prior-year period. First-quarter 2018 discretionary cash flow (non-GAAP) was $280.3 million, compared to $273.0 million in the prior-year period. First-quarter 2018 free cash flow (non-GAAP) was $88.6 million, compared to $56.9 million in the prior-year period.
First-quarter 2018 natural gas price realizations, including the impact of derivatives, were $2.44 per thousand cubic feet (Mcf), a decrease of eight percent compared to the prior-year period. Excluding the impact of derivatives, first-quarter 2018 natural gas price realizations were $2.50 per Mcf, representing a $0.50 discount to NYMEX settlement prices compared to a $0.67 discount in the prior-year comparable quarter. First-quarter 2018 oil price realizations, including the impact of derivatives, were $63.61 per barrel (Bbl), an increase of 36 percent compared to the prior-year period. NGL price realizations were $23.75 per Bbl, an increase of 15 percent compared to the prior-year period. First-quarter 2018 operating expenses (including financing) decreased to $1.58 per thousand cubic feet equivalent (Mcfe), a 21 percent improvement compared to the prior-year period.
Cabot incurred a total of $167.3 million of capital expenditures in the first-quarter of 2018 including $158.2 million of drilling and facilities capital; $7.4 million of leasehold acquisition capital; and $1.7 million of other capital. Additionally, the Company contributed $35.4 million to its equity pipeline investments in the first-quarter of 2018. See the supplemental table at the end of this press release reconciling the capital expenditures during the first-quarter of 2018.
Marcellus Shale Operational Highlights
During the first-quarter of 2018, the Company averaged 1,822 million cubic feet (Mmcf) per day of net Marcellus production, an increase of three percent sequentially compared to the fourth-quarter of 2017 despite the Company not placing any wells on production during the quarter. During the second-quarter of 2018, the Company plans to place 20.0 net wells on production, of which 16.0 net wells have already been turned to sales. Cabot expects to place an additional 60.0 net wells on production during the second half of the year to allow for the anticipated increase in production volumes associated with the in-service of new infrastructure projects beginning in June.
Cabot is currently operating three rigs and two completion crews in the Marcellus Shale.
Financial Position and Liquidity
As of March 31, 2018, Cabot had total debt of $1.5 billion and cash on hand of $964.9 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 18.8 percent and 0.5x, respectively, compared to 29.2 percent and 1.0x as of December 31, 2017.
Effective April 18, 2018, Cabot's borrowing base was unanimously reaffirmed by its 20 lenders at $3.2 billion. Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to Cabot. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.6 billion of liquidity. Cabot's next annual borrowing base redetermination is scheduled for April 2019.
Share Repurchase Program Update
During the first-quarter of 2018, Cabot repurchased 8.3 million shares at a weighted-average share price of $24.85. Subsequent to the end of the first-quarter, the Company repurchased an additional 1.6 million shares at a weighted-average share price of $23.40 under a Rule 10b5-1 plan, resulting in year-to-date repurchases of approximately 10.0 million shares at a weighted-average share price of $24.61. The Company has 20.1 million shares remaining under its current share repurchase program authorization. "Since we reactivated our share repurchase program in the second-quarter of 2017, Cabot has allocated approximately $370 million of capital to repurchasing approximately 15.0 million shares, further reinforcing the Company's commitment to increasing our return of capital to shareholders," commented Dinges.
Second-Quarter and Full-Year 2018 Guidance Update
Cabot has provided second-quarter 2018 net production guidance of 1,850 to 1,900 Mmcfe per day. The Company has also reaffirmed its total 2018 daily production growth guidance of 10 to 15 percent (18 to 23 percent on a divestiture-adjusted basis) and its full-year capital budget of $950 million.
As a result of the divestiture of Cabot's Eagle Ford Shale assets in the first-quarter, the Company has updated its operating expense guidance for the remaining nine months of 2018 to the following:
• Direct operations: |
$0.08 - $0.10 per Mcfe | ||
• Transportation and gathering: |
$0.66 - $0.68 per Mcfe | ||
• Taxes other than income: |
$0.02 - $0.03 per Mcfe | ||
• Depreciation, depletion and amortization: |
$0.48 - $0.53 per Mcfe | ||
• Interest expense: |
$0.09 - $0.11 per Mcfe | ||
• Cash general and administrative (ex. stock-based compensation): |
$40 - $42 million | ||
• Exploration: |
$30 - $32 million |
"Our 2018 plan remains on track to deliver double-digit corporate returns, double-digit growth in production per debt-adjusted share, and over $180 million of positive free cash flow at current prices," noted Dinges. "Additionally, we remain confident in our three-year plan that can generate between $1.6 and $2.5 billion of after-tax cumulative free cash flow based on a range of NYMEX prices of $2.75 to $3.25 per Mmbtu."
Conference Call Webcast
A conference call is scheduled for Friday, April 27, 2018, at 9:30 a.m. Eastern Time to discuss first quarter 2018 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||
Three Months Ended | |||||||
2018 |
2017 | ||||||
PRODUCTION VOLUMES |
|||||||
Natural gas (Bcf) |
164.6 |
163.8 |
|||||
Crude oil and condensate (Mbbl) |
754.0 |
921.0 |
|||||
Natural gas liquids (NGLs) (Mbbl) |
75.1 |
123.5 |
|||||
Equivalent production (Bcfe) |
169.6 |
170.1 |
|||||
AVERAGE SALES PRICE |
|||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.44 |
$ |
2.64 |
|||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.50 |
$ |
2.65 |
|||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
63.61 |
$ |
46.73 |
|||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
64.61 |
$ |
46.68 |
|||
NGL ($/Bbl) |
$ |
23.75 |
$ |
20.71 |
|||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||
Direct operations |
$ |
0.12 |
$ |
0.14 |
|||
Transportation and gathering |
0.66 |
0.73 |
|||||
Taxes other than income |
0.04 |
0.05 |
|||||
Exploration |
0.02 |
0.04 |
|||||
Depreciation, depletion and amortization |
0.48 |
0.79 |
|||||
General and administrative (excluding stock-based compensation) |
0.11 |
0.09 |
|||||
Stock-based compensation |
0.03 |
0.05 |
|||||
Interest expense |
0.12 |
0.12 |
|||||
$ |
1.58 |
$ |
2.01 |
||||
WELLS DRILLED (1) |
|||||||
Gross |
15 |
21 |
|||||
Net |
15.0 |
21.0 |
|||||
WELLS COMPLETED (1) |
|||||||
Gross |
11 |
25 |
|||||
Net |
11.0 |
24.0 |
(1) |
Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands, except per share amounts) |
2018 |
2017 | |||||
OPERATING REVENUES |
|||||||
Natural gas |
$ |
412,108 |
$ |
433,442 |
|||
Crude oil and condensate |
48,722 |
42,990 |
|||||
Gain on derivative instruments |
5,577 |
33,384 |
|||||
Brokered natural gas |
4,950 |
4,695 |
|||||
Other |
1,870 |
3,332 |
|||||
473,227 |
517,843 |
||||||
OPERATING EXPENSES |
|||||||
Direct operations |
20,070 |
24,641 |
|||||
Transportation and gathering |
112,125 |
123,474 |
|||||
Brokered natural gas |
4,950 |
4,046 |
|||||
Taxes other than income |
7,190 |
9,058 |
|||||
Exploration |
3,617 |
6,198 |
|||||
Depreciation, depletion and amortization |
82,128 |
135,100 |
|||||
General and administrative (excluding stock-based compensation) |
18,613 |
15,447 |
|||||
Stock-based compensation(1) |
5,447 |
8,253 |
|||||
254,140 |
326,217 |
||||||
Loss on equity method investments |
(994) |
(1,283) |
|||||
Loss on sale of assets |
(41,049) |
(223) |
|||||
INCOME FROM OPERATIONS |
177,044 |
190,120 |
|||||
Interest expense, net |
20,058 |
20,771 |
|||||
Other expense |
114 |
424 |
|||||
Income before income taxes |
156,872 |
168,925 |
|||||
Income tax expense |
39,641 |
63,205 |
|||||
NET INCOME |
$ |
117,231 |
$ |
105,720 |
|||
Earnings per share - Basic |
$ |
0.26 |
$ |
0.23 |
|||
Weighted-average common shares outstanding |
459,715 |
465,348 |
(1) |
Includes the impact of the Company's performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
March 31, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
1,236,118 |
$ |
764,957 |
|||
Properties and equipment, net (Successful efforts method) |
3,146,252 |
3,072,204 |
|||||
Assets held for sale |
6,807 |
778,855 |
|||||
Other assets |
149,224 |
111,328 |
|||||
$ |
4,538,401 |
$ |
4,727,344 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
510,491 |
$ |
630,050 |
|||
Long-term debt, net (excluding current maturities) |
1,218,231 |
1,217,891 |
|||||
Deferred income taxes |
291,280 |
227,030 |
|||||
Liabilities held for sale |
1,867 |
15,748 |
|||||
Other liabilities |
110,016 |
112,720 |
|||||
Stockholders' equity |
2,406,516 |
2,523,905 |
|||||
$ |
4,538,401 |
$ |
4,727,344 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands) |
2018 |
2017 | |||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||
Net income |
$ |
117,231 |
$ |
105,720 |
|||
Deferred income tax expense |
64,287 |
53,289 |
|||||
Loss on sale of assets |
41,049 |
223 |
|||||
Exploratory dry hole cost |
(60) |
2,842 |
|||||
Gain on derivative instruments |
(5,577) |
(33,384) |
|||||
Net cash paid in settlement of derivative instruments |
(26,131) |
(1,524) |
|||||
Income charges not requiring cash |
89,501 |
145,855 |
|||||
Changes in assets and liabilities |
(7,540) |
(3,643) |
|||||
Net cash provided by operating activities |
272,760 |
269,378 |
|||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||
Capital expenditures |
(156,257) |
(208,384) |
|||||
Proceeds from sale of assets |
646,545 |
374 |
|||||
Investment in equity method investments |
(35,418) |
(7,742) |
|||||
Net cash provided by (used in) investing activities |
454,870 |
(215,752) |
|||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||
Treasury stock repurchases |
(207,134) |
— |
|||||
Dividends paid |
(27,647) |
(9,306) |
|||||
Tax withholdings on vesting of stock awards |
(7,968) |
(5,414) |
|||||
Other |
— |
37 |
|||||
Net cash used in financing activities |
(242,749) |
(14,683) |
|||||
Net increase in cash and cash equivalents |
$ |
484,881 |
$ |
38,943 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income to Adjusted Net Income and Adjusted Earnings Per Share
Adjusted Net Income and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Three Months Ended | |||||||
(In thousands, except per share amounts) |
2018 |
2017 | |||||
As reported - net income |
$ |
117,231 |
$ |
105,720 |
|||
Reversal of selected items: |
|||||||
Loss on sale of assets |
41,049 |
223 |
|||||
Gain on derivative instruments(1) |
(31,708) |
(34,908) |
|||||
Stock-based compensation expense |
5,447 |
8,253 |
|||||
Tax effect on selected items |
(3,481) |
9,767 |
|||||
Adjusted net income |
$ |
128,538 |
$ |
89,055 |
|||
As reported - earnings per share |
$ |
0.26 |
$ |
0.23 |
|||
Per share impact of selected items |
0.02 |
(0.04) |
|||||
Adjusted earnings per share |
$ |
0.28 |
$ |
0.19 |
|||
Weighted-average common shares outstanding |
459,715 |
465,348 |
(1) |
This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Three Months Ended | ||||||||
(In thousands) |
2018 |
2017 | ||||||
Net cash provided by operating activities |
$ |
272,760 |
$ |
269,378 |
||||
Changes in assets and liabilities |
7,540 |
3,643 |
||||||
Discretionary cash flow |
280,300 |
273,021 |
||||||
Capital expenditures |
(156,257) |
(208,384) |
||||||
Investment in equity method investments |
(35,418) |
(7,742) |
||||||
Free cash flow |
$ |
88,625 |
$ |
56,895 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, loss on equity method investments and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Three Months Ended | |||||||
(In thousands) |
2018 |
2017 | |||||
Net income |
$ |
117,231 |
$ |
105,720 |
|||
Plus (less): |
|||||||
Interest expense, net |
20,058 |
20,771 |
|||||
Other expense |
114 |
424 |
|||||
Income tax expense |
39,641 |
63,205 |
|||||
Depreciation, depletion and amortization |
82,128 |
135,100 |
|||||
Exploration |
3,617 |
6,198 |
|||||
Loss on sale of assets |
41,049 |
223 |
|||||
Non-cash gain on derivative instruments |
(31,708) |
(34,908) |
|||||
Loss on equity method investments |
994 |
1,283 |
|||||
Stock-based compensation |
5,447 |
8,253 |
|||||
EBITDAX |
$ |
278,571 |
$ |
306,269 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Total Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Total Capitalization ratio.
(In thousands) |
March 31, |
December 31, | |||||
Current portion of long-term debt |
$ |
304,000 |
$ |
304,000 |
|||
Long-term debt, net |
1,218,231 |
1,217,891 |
|||||
Total debt |
$ |
1,522,231 |
$ |
1,521,891 |
|||
Stockholders' equity |
2,406,516 |
2,523,905 |
|||||
Total capitalization |
$ |
3,928,747 |
$ |
4,045,796 |
|||
Total debt |
$ |
1,522,231 |
$ |
1,521,891 |
|||
Less: Cash and cash equivalents |
(964,928) |
(480,047) |
|||||
Net debt |
$ |
557,303 |
$ |
1,041,844 |
|||
Net debt |
$ |
557,303 |
$ |
1,041,844 |
|||
Stockholders' equity |
2,406,516 |
2,523,905 |
|||||
Total adjusted capitalization |
$ |
2,963,819 |
$ |
3,565,749 |
|||
Total debt to total capitalization ratio |
38.7 |
% |
37.6 |
% | |||
Less: Impact of cash and cash equivalents |
19.9 |
% |
8.4 |
% | |||
Net debt to adjusted capitalization ratio |
18.8 |
% |
29.2 |
% |
Capital Expenditures | ||||||||
Three Months Ended | ||||||||
(In thousands) |
2018 |
2017 | ||||||
Cash paid for capital expenditures |
$ |
156,257 |
$ |
208,384 |
||||
Change in accrued capital costs |
11,032 |
6,695 |
||||||
Exploratory dry hole cost |
60 |
(2,842) |
||||||
Capital expenditures |
$ |
167,349 |
$ |
212,237 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-first-quarter-2018-results-300637761.html
SOURCE Cabot Oil & Gas Corporation
DENVER, April 25, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to announce it will host the 23rd annual edition of its popular The Oil & Gas Conference® this summer in Denver, Colo.
This year's oil and gas investment conference will be held August 19-22, 2018, at the Westin Denver Downtown. Investment and oil and gas professionals may register for the event through the conference website.
Conference Details: The Oil & Gas Conference® 23 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and learn about important energy topics affecting the global oil and gas industry. The forum fosters healthy dialogue and informal networking opportunities for attendees.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all of the U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The 2018 presenting companies include but are not limited to:
Additional Speakers: Global energy industry leaders, economists, market strategists, government officials and other energy experts will provide their insights on topics such as global commodities markets, the U.S. becoming a net energy exporter, and capital sources for energy development.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; Assured Partners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; and Credit Agricole CIB.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Q1 - 2019
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on AssuredPartners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy, and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
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SOURCE EnerCom, Inc.
HOUSTON, Feb. 23, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the fourth-quarter and full-year ended December 31, 2017. Additionally, the Company announced an expansion of its share repurchase program authorization to 30 million shares (or approximately 6.5 percent of its current shares outstanding).
Full-Year 2017 Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income (loss), EBITDAX, discretionary cash flow, free cash flow, ROCE, pre-tax present value of future net cash flows (pre-tax PV–10) and net debt to adjusted capitalization ratio.
"2017 marked another positive year for Cabot Oil & Gas as we continued to execute on our strategy for creating long-term shareholder value by delivering debt-adjusted per share growth; generating positive free cash flow; improving corporate returns on capital employed; increasing return of capital to shareholders; and maintaining a strong balance sheet," commented Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our strategy was rewarded in 2017 as Cabot delivered the highest total shareholder return in our peer group and outperformed the S&P 500 index. Given our relentless focus on delivering returns-focused per share growth, we have increased our share repurchase program authorization and modified the target metrics in our 2018 compensation program to focus on corporate returns and growth per debt-adjusted share, which are better-aligned with our disciplined capital allocation philosophy."
Full-Year 2017 Financial Results
Full-year 2017 equivalent production was 685.3 billion cubic feet equivalent (Bcfe), consisting of 655.6 billion cubic feet (Bcf) of natural gas, 4,440.9 thousand barrels (Mbbls) of crude oil and condensate, and 512.1 Mbbls of natural gas liquids (NGLs).
Full-year 2017 net income was $100.4 million, or $0.22 per share, compared to a net loss of $417.1 million, or $0.91 per share, in the prior-year period. Full-year 2017 adjusted net income (non-GAAP) was $244.5 million, or $0.53 per share, compared to an adjusted net loss of $97.3 million, or $0.21 per share, in the prior-year period. Full-year 2017 EBITDAX (non-GAAP) was $1,059.1 million, compared to $556.0 million in the prior-year period.
Full-year 2017 net cash provided by operating activities was $898.2 million, compared to $397.4 million in the prior-year period. Full-year 2017 discretionary cash flow (non-GAAP) was $976.1 million, compared to $460.7 million in the prior-year period. Full-year 2017 free cash flow (non-GAAP) was $154.5 million, compared to $57.1 million in in the prior-year period.
Full-year 2017 natural gas price realizations, including the impact of derivatives, were $2.31 per Mcf, a 36 percent improvement compared to the prior-year period. Excluding the impact of derivatives, full-year 2017 natural gas price realizations were $2.30 per Mcf, representing an $0.80 discount to NYMEX settlement prices. Full-year 2017 oil price realizations, including the impact of derivatives, were $48.16 per barrel (Bbl), an increase of 29 percent compared to the prior-year period. NGL price realizations were $19.47 per Bbl, an increase of 66 percent compared to the prior-year period. Full-year 2017 operating expenses (including financing) decreased to $2.02 per Mcfe, a seven percent improvement compared to the prior-year period.
Cabot incurred a total of $757.2 million of capital expenditures in 2017 including $637.2 million of drilling and facilities capital associated with drilling 91 gross (82.5 net) wells and completing 105 gross (94.2 net) wells; $102.3 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $17.7 million of other capital. Additionally, the Company contributed $57.0 million to its equity pipeline investments in 2017. See the supplemental table at the end of this press release reconciling the capital expenditures for the year.
Fourth-Quarter 2017 Financial Results
Fourth-quarter 2017 equivalent production was 172.6 Bcfe, consisting of 164.4 Bcf of natural gas, 1,238.0 Mbbls of crude oil and condensate, and 131.5 Mbbls of NGLs. On a divestiture-adjusted basis (which reflects the impact of the West Virginia disposition that closed in the third-quarter), Cabot's equivalent production increased four percent sequentially compared to the third-quarter. Natural gas production for the fourth-quarter came in on the lower end of the Company's guidance range primarily due to delayed in-service dates for two new third-party compressor stations, of which one was placed in-service in January 2018 and one that is expected to be in-service by the end of the first quarter.
Fourth-quarter 2017 net loss was $44.4 million, or $0.10 per share, compared to net loss of $292.8 million, or $0.63 per share, in the prior-year period. Fourth-quarter 2017 adjusted net income (non-GAAP) was $59.5 million, or $0.13 per share, compared to adjusted net income of $5.1 million, or $0.01 per share, in the prior-year period. Fourth-quarter 2017 EBITDAX (non-GAAP) was $259.8 million, compared to $187.8 million in the prior-year period.
Fourth-quarter 2017 net cash provided by operating activities was $179.1 million, compared to $139.7 million in the prior-year period. Fourth-quarter 2017 discretionary cash flow (non-GAAP) was $240.1 million, compared to $163.6 million in the prior-year period. Fourth-quarter 2017 free cash flow (non-GAAP) was $28.7 million, compared to $29.1 million in in the prior-year period.
Fourth-quarter 2017 natural gas price realizations, including the impact of derivatives, were $2.18 per Mcf, a 12 percent improvement compared to the prior-year period. Excluding the impact of derivatives, fourth-quarter 2017 natural gas price realizations were $2.15 per Mcf, representing a $0.78 discount to NYMEX settlement prices. Fourth-quarter 2017 oil price realizations, including the impact of derivatives, were $54.54 per Bbl, an increase of 27 percent compared to the prior-year period. NGL price realizations were $23.51 per Bbl, an increase of 70 percent compared to the prior-year period. Fourth-quarter 2017 operating expenses (including financing) decreased to $2.01 per Mcfe, a two percent improvement compared to the prior-year period.
Cabot incurred a total of $174.5 million of capital expenditures in the fourth-quarter of 2017 including $162.0 million of drilling and facilities capital associated with drilling 20 gross (20.0 net) wells and completing 24 gross (24.0 net) wells; $4.4 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $8.1 million of other capital. Additionally, the Company contributed $33.7 million to its equity pipeline investments in 2017. See the supplemental table at the end of this press release reconciling the capital expenditures during the fourth-quarter of 2017.
Year-End 2017 Financial Position and Liquidity
As of December 31, 2017, Cabot had total debt of $1.5 billion and cash on hand of $480.0 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 29.2 percent and 1.0x, respectively, compared to 28.5 percent and 1.8x as of December 31, 2016.
Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to the Company. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Share Repurchase Program Update
During the fourth-quarter of 2017, Cabot repurchased 2.0 million shares at a weighted-average share price of $27.72. For the full-year 2017, the Company repurchased 5.0 million shares at a weighted-average share price of $24.52.
The Board of Directors has authorized an increase in the Company's share repurchase program to 30 million shares (or approximately 6.5 percent of its current shares outstanding). All purchases will be made in accordance with applicable securities laws from time to time in open market or private transactions, depending on market conditions, and may be discontinued at any time. Based on the closing share price on February 22, 2018, the program implies approximately $720 million of potential share repurchases. "Subsequent to the closing of our Eagle Ford Shale divestiture (which is expected to close on February 28, 2018), we will have approximately $1.2 billion of cash on hand. This cash position, along with our anticipated free cash flow in 2018, provides us the financial flexibility to execute on an expanded share repurchase program while continuing to reinvest in returns-focused, organic growth from our existing asset base," stated Dinges.
Year-End 2017 Proved Reserves
Cabot reported year-end proved reserves of 9.7 trillion cubic feet equivalent (Tcfe), an increase of 13 percent over year-end 2016. Specific highlights from the Company's year-end reserve report include:
The table below reconciles the components driving the 2017 reserve increase:
Proved Reserves Reconciliation (in Bcfe) | |
Balance at December 31, 2016 |
8,576 |
Revisions of prior estimates |
928 |
Extensions, discoveries and other additions |
1,236 |
Sales |
(329) |
Production |
(685) |
Balance at December 31, 2017 |
9,726 |
As of December 31, 2017, 96 percent of Cabot's year-end proved reserves were natural gas and 96 percent were located in the Marcellus Shale. Approximately 64 percent of the year-end proved reserves were classified as proved developed and 36 percent were classified as proved undeveloped (PUD), including eight percent of drilled and uncompleted PUDs.
Total costs incurred during 2017 were $761.0 million, which included $617.5 million for development costs, $41.2 million for exploration costs, and $102.3 million for lease acquisition costs.
The SEC prices used for reporting Cabot's year-end 2017 proved reserves, which have been adjusted for basis and quality differentials, were $2.33 per Mcf for natural gas and $49.26 per Bbl for crude oil, representing a 34 percent and 31 percent year-over-year increase, respectively. Assuming the SEC prices, the pre-tax PV–10 (non-GAAP) of the year-end 2017 proved reserves was $6.0 billion.
Tax Reform Impact
On December 22, 2017, the U.S. enacted tax legislation referred to as the Tax Cuts and Jobs Act (the "Tax Act"), which made significant changes to U.S. federal income tax law. These changes include, among others, a permanent reduction of the U.S. corporate income tax rate from a top marginal rate of 35 percent to a flat rate of 21 percent; elimination of the corporate alternative minimum tax (AMT); and immediate deductions for certain new investments instead of deductions for depreciation expense over time. Overall, the Company expects the provisions of the Tax Act to favorably impact its future effective tax rate, after-tax earnings, and cash flows.
As a result of the enactment of the Tax Act, Cabot recorded an income tax benefit of $242.9 million in the fourth-quarter of 2017 resulting from the remeasurement of the Company's net deferred tax liabilities based on the new lower corporate income tax rate. As of December 31, 2017, the Company had AMT credit carryforwards of $208.6 million, which do not expire and can be used to offset regular income taxes in future years. Under the new Tax Act, the Company may claim a refund of 50 percent of the remaining AMT credits (to the extent the credits exceed regular tax for the year) in 2018, 2019, and 2020. Any AMT credits remaining after 2020 will be refunded in 2021. The Company expects a net refund of $97.1 million related to 2018.
First-Quarter and Full-Year 2018 Guidance Update
Cabot has provided first-quarter 2018 net production guidance of 1,775 to 1,825 million cubic feet (Mmcf) per day for natural gas; 7,500 to 8,000 Bbls per day for crude oil and condensate; and 700 to 800 Bbls per day for NGLs. This guidance range assumes a February 28, 2018 closing date for the Company's previously announced Eagle Ford divestiture and reflects the impact of the previously mentioned in-service delay for two new third-party compressor stations in the Marcellus.
Cabot has reaffirmed its 2018 daily production growth guidance of 10 to 15 percent (18 to 23 percent on a divestiture-adjusted basis to reflect the impact of the previously announced Eagle Ford, East Texas, and West Virginia dispositions). "Our 2018 production growth is weighted toward the second half of the year driven by anticipated mid-year in-service dates for the Moxie Freedom power plant, Lackawanna Energy Center power plant, and Atlantic Sunrise pipeline," noted Dinges. "We anticipate sequential quarterly growth of approximately six, eleven and thirteen percent in the second, third, and fourth quarters, respectively, resulting in a divestiture-adjusted exit-to-exit production growth rate of over 35 percent."
The Company has also updated its capital budget to $950 million (consistent with the midpoint of the previously announced 2018 budget) as follows:
• Marcellus Shale: |
$800 million | |||||||||||||||
• Exploration Areas: |
$75 million | |||||||||||||||
• Pipeline Investments: |
$60 million | |||||||||||||||
• Corporate: |
$15 million |
The Company plans to average three rigs and two completion crews in the Marcellus Shale during 2018, resulting in 85 net wells drilled and 95 net wells completed. The average lateral length for the 2018 Marcellus Shale drilling program is 8,300 feet and the expected average well cost is $8.3 million ($1,000 per foot) for drilling, completion and facilities. This average well cost incorporates anticipated cost inflation resulting from new service contracts, offset by efficiencies associated with implementing the Generation 5 well design across the majority of the program. "Our Generation 5 wells continue to track our 4.4 Bcf per 1,000 lateral feet type curve, which gives us the confidence to implement this well design across the majority of our program moving forward due to the improved economics from this more capital-efficient design," said Dinges.
Additionally, the Company has updated its 2018 operating expense guidance to the following to reflect the impact of the previously announced divestitures:
• Direct operations: |
$0.09 - $0.11 per Mcfe |
• Transportation and gathering: |
$0.66 - $0.68 per Mcfe |
• Taxes other than income: |
$0.02 - $0.03 per Mcfe |
• Depreciation, depletion and amortization: |
$0.50 - $0.60 per Mcfe |
• Interest expense: |
$0.09 - $0.11 per Mcfe |
• Cash general and administrative (ex. stock-based compensation): |
$60 million |
• Exploration: |
$35 million |
"Our forecasted operating expenses for the year are now expected to be below $1.60 per Mcfe, representing over a 20 percent improvement relative to 2017," highlighted Dinges. "This industry-leading cost structure will allow us to continue to generate profitability and deliver strong corporate returns on capital even at the lows of the natural gas price cycle. Our 2018 plan is expected to generate approximately $180 million of free cash flow at an average NYMEX price of $2.75 per Mmbtu and can still be self-funding and generate a double-digit ROCE at an average NYMEX price as low as $2.50 per Mmbtu."
For further disclosure on Cabot's natural gas pricing exposure by index and corporate tax guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Updated Three-Year Outlook
As a result of the previously announced divestiture of the Eagle Ford properties and the recent change in U.S. federal income tax law, the Company has provided an updated three-year outlook for the total company including the impact of income taxes, corporate overhead and interest expense. From 2018 to 2020, the Company expects to deliver a three-year production compound annual growth rate (CAGR) of 17 to 21 percent (or 20 to 24 percent on a divestiture-adjusted basis). Based on a range of NYMEX prices of $2.75 to $3.25 per Mmbtu, the Company expects to deliver between $1.6 and $2.5 billion of after-tax cumulative free cash flow (non-GAAP) while delivering significant growth in net income, discretionary cash flow (non-GAAP), and ROCE (non-GAAP). "We believe the combination of growth, free cash flow and corporate returns expected during this three-year period are not only best-in-class in the exploration and production sector, but are extremely competitive when compared to the broader equity market," emphasized Dinges.
The Company assumed no capital was allocated to exploration in 2019 and 2020; however, this is subject to change based on the initial results from the ongoing testing in the Company's exploratory areas. For further disclosure on the Company's three-year plan assumptions, please see the current investor presentation in the Investor Relations section of the Company's website.
Conference Call Webcast and Supplemental Earnings Materials
A conference call is scheduled for Friday, February 23, 2018, at 9:30 a.m. Eastern Time to discuss fourth quarter and full-year 2017 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "outlook", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
164.4 |
158.6 |
655.6 |
600.4 |
|||||||||||
Crude oil and condensate (Mbbl) |
1,238.0 |
822.7 |
4,440.9 |
4,013.1 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
131.5 |
106.5 |
512.1 |
441.2 |
|||||||||||
Equivalent production (Bcfe) |
172.6 |
164.2 |
685.3 |
627.1 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.18 |
$ |
1.94 |
$ |
2.31 |
$ |
1.70 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.15 |
$ |
1.96 |
$ |
2.30 |
$ |
1.70 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
54.54 |
$ |
42.94 |
$ |
48.16 |
$ |
37.30 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
54.77 |
$ |
44.36 |
$ |
47.81 |
$ |
37.65 |
|||||||
NGL ($/Bbl) |
$ |
23.51 |
$ |
13.84 |
$ |
19.47 |
$ |
11.74 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.14 |
$ |
0.14 |
$ |
0.15 |
$ |
0.16 |
|||||||
Transportation and gathering |
0.69 |
0.69 |
0.70 |
0.70 |
|||||||||||
Taxes other than income |
0.04 |
0.03 |
0.05 |
0.05 |
|||||||||||
Exploration |
0.03 |
0.09 |
0.03 |
0.04 |
|||||||||||
Depreciation, depletion and amortization |
0.83 |
0.86 |
0.83 |
0.94 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.11 |
0.10 |
0.09 |
0.10 |
|||||||||||
Stock-based compensation |
0.05 |
0.02 |
0.05 |
0.04 |
|||||||||||
Interest expense |
0.12 |
0.12 |
0.12 |
0.14 |
|||||||||||
$ |
2.01 |
$ |
2.05 |
$ |
2.02 |
$ |
2.17 |
||||||||
WELLS DRILLED(1) |
|||||||||||||||
Gross |
20 |
12 |
91 |
40 |
|||||||||||
Net |
20.0 |
10.0 |
82.5 |
38.0 |
|||||||||||
WELLS COMPLETED(1) |
|||||||||||||||
Gross |
24 |
25 |
105 |
76 |
|||||||||||
Net |
24.0 |
25.0 |
94.2 |
76.0 |
____________________________________________ | |
(1) |
Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 | |||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
353,989 |
$ |
311,580 |
$ |
1,506,078 |
$ |
1,022,590 |
|||||||
Crude oil and condensate |
67,810 |
36,496 |
212,338 |
151,106 |
|||||||||||
Gain (loss) on derivative instruments |
(29,427) |
(37,664) |
16,926 |
(38,950) |
|||||||||||
Brokered natural gas |
4,957 |
4,152 |
17,217 |
13,569 |
|||||||||||
Other |
3,174 |
1,927 |
11,660 |
7,362 |
|||||||||||
400,503 |
316,491 |
1,764,219 |
1,155,677 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
24,125 |
23,557 |
102,310 |
100,696 |
|||||||||||
Transportation and gathering |
119,530 |
113,659 |
481,439 |
436,542 |
|||||||||||
Brokered natural gas |
4,990 |
3,259 |
15,252 |
10,785 |
|||||||||||
Taxes other than income |
6,925 |
5,486 |
33,487 |
29,223 |
|||||||||||
Exploration |
4,903 |
14,553 |
21,526 |
27,662 |
|||||||||||
Depreciation, depletion and amortization |
143,128 |
141,218 |
568,817 |
590,128 |
|||||||||||
Impairment of oil and gas properties and other assets(1) |
414,256 |
435,619 |
482,811 |
435,619 |
|||||||||||
General and administrative (excluding stock-based compensation) |
19,022 |
15,489 |
63,745 |
59,665 |
|||||||||||
Stock-based compensation(2) |
7,863 |
2,952 |
34,041 |
25,968 |
|||||||||||
744,742 |
755,792 |
1,803,428 |
1,716,288 |
||||||||||||
Loss on equity method investments(3) |
(96,500) |
(2,685) |
(100,486) |
(2,477) |
|||||||||||
(Gain) loss on sale of assets |
1,933 |
(1,089) |
(11,565) |
(1,857) |
|||||||||||
LOSS FROM OPERATIONS |
(438,806) |
(443,075) |
(151,260) |
(564,945) |
|||||||||||
Interest expense, net |
20,410 |
20,515 |
82,130 |
88,336 |
|||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
|||||||||||
Other expense (income) |
18 |
402 |
(4,955) |
1,609 |
|||||||||||
Loss before income taxes |
(459,234) |
(463,992) |
(228,435) |
(659,599) |
|||||||||||
Income tax benefit(4) |
(414,793) |
(171,232) |
(328,828) |
(242,475) |
|||||||||||
NET INCOME (LOSS) |
$ |
(44,441) |
$ |
(292,760) |
$ |
100,393 |
$ |
(417,124) |
|||||||
Earnings (loss) per share - Basic |
$ |
(0.10) |
$ |
(0.63) |
$ |
0.22 |
$ |
(0.91) |
|||||||
Weighted-average common shares outstanding |
462,371 |
465,150 |
463,735 |
456,847 |
____________________________________ | |
(1) |
Includes the impairment of our Eagle Ford Shale oil and gas properties in south Texas in the fourth quarter of 2017. Includes the impairment of oil and gas properties and the related pipeline assets in West Virginia and Virginia in the fourth quarter of 2016. |
(2) |
Includes the impact of our performance share awards and restricted stock. |
(3) |
Includes the $95.9 million other than temporary impairment of our investment in Constitution. |
(4) |
Includes the impact of the remeasurement of our net deferred income tax liabilities based on the new corporate income tax rate associated with the Tax Act in the fourth quarter of 2017. The remeasurement resulted in an income tax benefit of $242.9 million. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
December 31, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
764,957 |
$ |
715,881 |
|||
Properties and equipment, net (Successful efforts method) |
3,072,204 |
4,250,125 |
|||||
Assets held for sale |
778,855 |
— |
|||||
Other assets |
111,328 |
156,563 |
|||||
$ |
4,727,344 |
$ |
5,122,569 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
630,050 |
$ |
257,812 |
|||
Long-term debt, net (excluding current maturities) |
1,217,891 |
1,520,530 |
|||||
Deferred income taxes |
227,030 |
579,447 |
|||||
Liabilities held for sale |
15,748 |
— |
|||||
Other liabilities |
112,720 |
197,113 |
|||||
Stockholders' equity |
2,523,905 |
2,567,667 |
|||||
$ |
4,727,344 |
$ |
5,122,569 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income (loss) |
$ |
(44,441) |
$ |
(292,760) |
$ |
100,393 |
$ |
(417,124) |
|||||||
Deferred income tax benefit |
(410,844) |
(171,294) |
(321,113) |
(230,707) |
|||||||||||
Impairment of oil and gas properties and other assets |
414,256 |
435,619 |
482,811 |
435,619 |
|||||||||||
(Gain) loss on sale of assets |
(1,933) |
1,089 |
11,565 |
1,857 |
|||||||||||
Exploratory dry hole cost |
978 |
10,102 |
3,820 |
10,120 |
|||||||||||
(Gain) loss on derivative instruments |
29,427 |
37,664 |
(16,926) |
38,950 |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
4,469 |
(4,886) |
8,056 |
(1,682) |
|||||||||||
Income charges not requiring cash |
248,231 |
148,029 |
707,496 |
623,670 |
|||||||||||
Changes in assets and liabilities |
(61,030) |
(23,827) |
(77,942) |
(63,262) |
|||||||||||
Net cash provided by operating activities |
179,113 |
139,736 |
898,160 |
397,441 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(177,745) |
(130,120) |
(764,558) |
(375,153) |
|||||||||||
Proceeds from sale of assets |
82,733 |
1,351 |
115,444 |
50,419 |
|||||||||||
Investment in equity method investments |
(33,657) |
(4,308) |
(57,039) |
(28,484) |
|||||||||||
Net cash used in investing activities |
(128,669) |
(133,077) |
(706,153) |
(353,218) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net borrowings (repayments) of debt |
— |
— |
— |
(497,000) |
|||||||||||
Treasury stock repurchases |
(55,486) |
— |
(123,741) |
— |
|||||||||||
Sale of common stock, net |
— |
— |
— |
995,279 |
|||||||||||
Dividends paid |
(23,131) |
(9,302) |
(78,838) |
(36,187) |
|||||||||||
Tax withholding on vesting of stock awards |
(2,044) |
(8) |
(7,973) |
(5,064) |
|||||||||||
Capitalized debt issuance costs |
— |
— |
— |
(3,223) |
|||||||||||
Other |
8 |
— |
50 |
— |
|||||||||||
Net cash (used in) provided by financing activities |
(80,653) |
(9,310) |
(210,502) |
453,805 |
|||||||||||
Net (decrease) increase in cash and cash equivalents |
$ |
(30,209) |
$ |
(2,651) |
$ |
(18,495) |
$ |
498,028 |
Explanation and Reconciliation of Non-GAAP Financial Measures
We report our financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, we believe certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of our peers and of prior periods. In addition, we believe these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
We have also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, we cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income (Loss) to Adjusted Net Income (Loss) and Adjusted Earnings Per Share
Adjusted Net Income (Loss) and Adjusted Earnings per Share are presented based on our belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income (Loss) and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 | |||||||||||
As reported - net income (loss) |
$ |
(44,441) |
$ |
(292,760) |
$ |
100,393 |
$ |
(417,124) |
|||||||
Reversal of selected items: |
|||||||||||||||
Impairment of oil and gas properties and other assets(1) |
414,256 |
435,619 |
482,811 |
435,619 |
|||||||||||
Impairment of equity method investments(2) |
95,945 |
— |
95,945 |
— |
|||||||||||
(Gain) loss on sale of assets |
(1,933) |
1,089 |
11,565 |
1,857 |
|||||||||||
(Gain) loss on derivative instruments(3) |
33,896 |
32,778 |
(8,870) |
37,268 |
|||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
|||||||||||
Drilling rig termination fees |
— |
— |
— |
1,655 |
|||||||||||
Stock-based compensation expense |
7,863 |
2,952 |
34,041 |
25,968 |
|||||||||||
Severance expense |
21 |
— |
3,213 |
209 |
|||||||||||
OPEB curtailment |
(67) |
— |
(4,917) |
— |
|||||||||||
Tax effect on selected items |
(203,211) |
(174,567) |
(226,787) |
(187,443) |
|||||||||||
Impact of 2017 tax reform |
(242,875) |
— |
(242,875) |
— |
|||||||||||
Adjusted net income (loss) |
$ |
59,454 |
$ |
5,111 |
$ |
244,519 |
$ |
(97,282) |
|||||||
As reported - earnings (loss) per share |
$ |
(0.10) |
$ |
(0.63) |
$ |
0.22 |
$ |
(0.91) |
|||||||
Per share impact of selected items |
0.23 |
0.64 |
0.31 |
0.70 |
|||||||||||
Adjusted earnings (loss) per share |
$ |
0.13 |
$ |
0.01 |
$ |
0.53 |
$ |
(0.21) |
|||||||
Weighted-average common shares outstanding |
462,371 |
465,150 |
463,735 |
456,847 |
_____________________________________ | |
(1) |
This amount represents the non-cash impairment of our Eagle Ford Shale oil and gas properties located in south Texas in the fourth quarter of 2017 and the non-cash impairment of our West Virginia and Virginia properties in the fourth quarter of 2016. |
(2) |
This amount represents the non-cash other than temporary impairment of our investment in Constitution recorded in Loss on equity method investments in the Condensed Consolidated Statement of Operations. |
(3) |
This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in Gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Return on Capital Employed
Return on Capital Employed (ROCE) is defined as adjusted net income (loss) (defined above) plus after-tax net interest expense divided by average capital employed, which is defined as total debt plus stockholders' equity. ROCE is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our profitability and the efficiency with which we have employed capital over time relative to other companies. ROCE is not a measure of financial performance under GAAP and should not be considered an alternative to net income.
(In thousands) |
2017 |
2016 | ||||||
Interest expense, net |
$ |
82,130 |
$ |
88,336 |
||||
Tax benefit on interest expense, net |
(30,346) |
(32,640) |
||||||
After-tax interest expense, net (A) |
51,784 |
55,696 |
||||||
As reported - net income (loss) |
100,393 |
(417,124) |
||||||
Adjustments to as reported - net income (loss), net of tax |
144,126 |
319,842 |
||||||
Adjusted net income (loss) (B) |
244,519 |
(97,282) |
||||||
Adjusted net income (loss) before interest expense, net (A + B) |
$ |
296,303 |
$ |
(41,586) |
||||
Total debt - beginning |
$ |
1,520,530 |
$ |
2,016,139 |
||||
Stockholders' equity - beginning |
2,567,667 |
2,009,188 |
||||||
Capital employed - beginning |
4,088,197 |
4,025,327 |
||||||
Total debt - ending |
1,521,891 |
1,520,530 |
||||||
Stockholders' equity - ending |
2,523,905 |
2,567,667 |
||||||
Capital employed - ending |
4,045,796 |
4,088,197 |
||||||
Average capital employed - (C) |
$ |
4,066,997 |
$ |
4,056,762 |
||||
Return on average capital employed (ROCE) (A+B) / C |
7.3% |
(1.0)% |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on our belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended |
Twelve Months Ended December 31, | |||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | ||||||||||||
Net cash provided by operating activities |
179,113 |
139,736 |
898,160 |
397,441 |
||||||||||||
Changes in assets and liabilities |
61,030 |
23,827 |
77,942 |
63,262 |
||||||||||||
Discretionary cash flow |
240,143 |
163,563 |
976,102 |
460,703 |
||||||||||||
Capital expenditures |
(177,745) |
(130,120) |
(764,558) |
(375,153) |
||||||||||||
Investment in equity method investments |
(33,657) |
(4,308) |
(57,039) |
(28,484) |
||||||||||||
Free cash flow |
$ |
28,741 |
$ |
29,135 |
$ |
154,505 |
$ |
57,066 |
||||||||
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, loss on equity method investments, and stock-based compensation expense. EBITDAX is presented based on our belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
Net income (loss) |
$ |
(44,441) |
$ |
(292,760) |
$ |
100,393 |
$ |
(417,124) |
|||||||
Plus (less): |
|||||||||||||||
Interest expense, net |
20,410 |
20,515 |
82,130 |
88,336 |
|||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
|||||||||||
Other expense (income) |
18 |
402 |
(4,955) |
1,609 |
|||||||||||
Income tax benefit |
(414,793) |
(171,232) |
(328,828) |
(242,475) |
|||||||||||
Depreciation, depletion and amortization |
143,128 |
141,218 |
568,817 |
590,128 |
|||||||||||
Impairment of oil and gas properties and other assets |
414,256 |
435,619 |
482,811 |
435,619 |
|||||||||||
Exploration |
4,903 |
14,553 |
21,526 |
27,662 |
|||||||||||
(Gain) loss on sale of assets |
(1,933) |
1,089 |
11,565 |
1,857 |
|||||||||||
Non-cash (gain) loss on derivative instruments |
33,896 |
32,778 |
(8,870) |
37,268 |
|||||||||||
Loss on equity method investments |
96,500 |
2,685 |
100,486 |
2,477 |
|||||||||||
Stock-based compensation |
7,863 |
2,952 |
34,041 |
25,968 |
|||||||||||
EBITDAX |
$ |
259,807 |
$ |
187,819 |
$ |
1,059,116 |
$ |
556,034 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and we believe this ratio is useful to investors in determining our leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Total Capitalization ratio are non-GAAP measures which we believe are also useful to investors since we have the ability to and may decide to use a portion of our cash and cash equivalents to retire debt. Additionally, as we may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Total Capitalization ratio.
(In thousands) |
December 31, |
December 31, | |||||
Current portion of long-term debt |
$ |
304,000 |
$ |
— |
|||
Long-term debt, net |
1,217,891 |
1,520,530 |
|||||
Total debt |
$ |
1,521,891 |
$ |
1,520,530 |
|||
Stockholders' equity |
2,523,905 |
2,567,667 |
|||||
Total capitalization |
$ |
4,045,796 |
$ |
4,088,197 |
|||
Total debt |
$ |
1,521,891 |
$ |
1,520,530 |
|||
Less: Cash and cash equivalents |
(480,047) |
(498,542) |
|||||
Net debt |
$ |
1,041,844 |
$ |
1,021,988 |
|||
Net debt |
$ |
1,041,844 |
$ |
1,021,988 |
|||
Stockholders' equity |
2,523,905 |
2,567,667 |
|||||
Total adjusted capitalization |
$ |
3,565,749 |
$ |
3,589,655 |
|||
Total debt to total capitalization ratio |
37.6 |
% |
37.2 |
% | |||
Less: Impact of cash and cash equivalents |
8.4 |
% |
8.7 |
% | |||
Net debt to adjusted capitalization ratio |
29.2 |
% |
28.5 |
% |
Capital Expenditures
Quarter Ended |
Twelve Months Ended | |||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | ||||||||||||
Cash paid for capital expenditures |
$ |
177,745 |
$ |
130,120 |
$ |
764,558 |
$ |
375,153 |
||||||||
Change in accrued capital costs |
(2,309) |
(9,904) |
(3,516) |
7,168 |
||||||||||||
Exploratory dry hole cost |
(978) |
(10,102) |
(3,820) |
(10,120) |
||||||||||||
Capital expenditures |
$ |
174,458 |
$ |
110,114 |
$ |
757,222 |
$ |
372,201 |
Pre-tax Present Value of Future Net Cash Flows Calculation and Reconciliation
(In thousands) |
December 31, |
December 31, | |||||
Standardized Measure of Discounted Future Net Cash Flows |
$ |
5,010,446 |
$ |
2,234,767 |
|||
Plus: Future Income Tax Expenses, discounted at 10% annual rate |
955,240 |
380,276 |
|||||
Pre-tax Present Value of Future Net Cash Flows, discounted at 10% annual rate |
$ |
5,965,686 |
$ |
2,615,043 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-fourth-quarter-and-full-year-2017-results-expands-share-repurchase-program-authorization-300603225.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 29, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its fourth quarter and year end 2017 earnings conference call on Friday, February 23, 2018 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-fourth-quarter-and-year-end-2017-earnings-release-date-and-conference-call-300589635.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 3, 2018 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a 20 percent increase in its regular quarterly dividend to six cents ($0.06) per share on the Company's common stock. The dividend will be paid on February 7, 2018 to all shareholders of record as of the close of business on January 24, 2018.
"Today's decision to increase the Company's dividend for the second consecutive year highlights our commitment to increasing our return of capital to shareholders," commented Dan O. Dinges, Chairman, President and Chief Executive Officer. "We firmly believe that our strong balance sheet and our ability to deliver double-digit growth per debt-adjusted share from our Marcellus Shale asset while generating positive free cash flow will allow us to continue to return capital to shareholders through sustainable dividend growth and opportunistic share repurchases."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-dividend-increase-of-20-percent-300577258.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Dec. 20, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") announced today that it has reached an agreement to sell its operated and non-operated Eagle Ford Shale assets to an affiliate of Venado Oil & Gas LLC for $765 million. The divestiture includes approximately 74,500 net acres (~65,100 operated and ~9,400 non-operated) of Eagle Ford Shale leasehold primarily located in Frio and Atascosa counties. Production from these properties during the third quarter of 2017 was 15,656 barrels of oil equivalent (Boe) per day. This transaction is expected to close during the first quarter of 2018, subject to customary closing conditions and adjustments. Separately, the Company announced the sale of its remaining East Texas assets to an undisclosed buyer. This transaction is expected to close on or before July 1, 2018, subject to customary closing conditions and adjustments.
Cash proceeds from these transactions, in addition to the Company's current cash position and its outlook for significant free cash flow generation during its three-year plan through 2020, are expected to allow Cabot to continue to enhance shareholder value by:
"Beginning over a decade ago, Cabot began the process of transforming the Company into one of the lowest cost operators in the industry, which has allowed us to create value for shareholders by delivering returns-focused growth while maintaining a strong balance sheet throughout the commodity cycles," commented Dan O. Dinges, Chairman, President and Chief Executive Officer. "These transactions represent a further step in our transformation process and accelerate the value of these assets while improving Cabot's cost structure and corporate returns. These assets accounted for only five percent of our year-to-date total equivalent production and four percent of our proved reserves. Pro forma for these transactions and the previously announced divestiture of the Company's legacy West Virginia properties, Cabot's operating expenses per unit (including interest expense) are expected to decrease by almost 20 percent to approximately $1.65 per thousand cubic feet equivalent (Mcfe) in 2018. In a higher oil price environment, the Eagle Ford Shale assets were a nice complement to our Marcellus Shale position and provided capital allocation optionality. However, based on our current outlook for the oil markets and the resulting rates of return from these assets relative to our Marcellus Shale returns, we did not plan to allocate any incremental capital to the Eagle Ford Shale above the current maintenance capital levels."
Cabot expects to record a non-cash, after-tax impairment on the Eagle Ford Shale assets of approximately $270 to $280 million (based on estimated net book value as of November 30, 2017) in the fourth quarter of 2017.
Scotiabank served as financial advisor and Norton Rose Fulbright US LLP served as legal counsel to Cabot on the Eagle Ford Shale transaction. Kirkland & Ellis LLP served as Venado's legal counsel on the Eagle Ford Shale transaction.
2018 Guidance Update
Based on the announced divestitures, Cabot has updated its 2018 daily production growth guidance range to 10 to 15 percent (18 to 23 percent pro forma for the Eagle Ford, East Texas, and West Virginia divestitures). The Company has also updated its 2018 capital budget range to $900 million to $1.0 billion consisting of the following:
• |
Marcellus Shale: |
$750 - $850 million | |
• |
Exploration Areas: |
$75 million | |
• |
Pipeline Investments: |
$60 million | |
• |
Corporate: |
$15 million |
Additionally, the Company has updated its 2018 operating expense guidance to the following to reflect the impact of the announced divestitures:
• |
Direct operations: |
$0.09 - $0.11 per Mcfe | |
• |
Transportation and gathering: |
$0.68 - $0.70 per Mcfe | |
• |
Taxes other than income: |
$0.05 - $0.06 per Mcfe | |
• |
Depreciation, depletion and amortization: |
$0.55 - $0.65 per Mcfe | |
• |
Interest expense: |
$0.09 - $0.10 per Mcfe | |
• |
Cash general and administrative (ex. stock-based compensation): |
$55 - $60 million | |
• |
Exploration: |
$30 - $35 million |
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, capital budgets, estimated expenses, dividend growth, share repurchases, strategic pursuits and goals, market prices, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "target", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
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SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 27, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported results for the third quarter of 2017.
Third Quarter 2017 Strategic Highlights
Third Quarter 2017 Financial and Operating Highlights
See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including adjusted net income (loss), EBITDAX, discretionary cash flow, free cash flow and net debt to adjusted capitalization ratio.
"Our disciplined approach to managing the business continued this quarter as we generated positive free cash flow despite lower than anticipated natural gas price realizations due to wider regional differentials," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "We remain committed to delivering positive free cash flow in 2017 and beyond, while continuing to focus on improving our corporate returns and increasing our return of capital to shareholders through prudent capital allocation."
Third Quarter 2017 Financial Results
Equivalent production for the third quarter of 2017 was 169.5 billion cubic feet equivalent (Bcfe), consisting of 161.2 billion cubic feet (Bcf) of natural gas, 1,268.0 thousand barrels (Mbbls) of crude oil and condensate, and 124.7 Mbbls of natural gas liquids (NGLs). Natural gas production for the third quarter was at the low end of the Company's guidance range due to longer than anticipated downtime at third-party compressor stations and a delay in placing a seven-well pad on production due to weather-related pipeline construction delays. NGLs production was below the Company's guidance range due to downtime at a third-party processing plant in the Eagle Ford that was impacted by Hurricane Harvey.
Net income for the third quarter of 2017 was $17.6 million, or $0.04 per share, compared to a net loss of $10.3 million, or $0.02 per share, for the third quarter of 2016. Adjusted net income was $32.0 million, or $0.07 per share, compared to an adjusted net loss of $16.7 million, or $0.04 per share, for the third quarter of 2016. EBITDAX for the third quarter of 2017 was $218.6 million, compared to $139.2 million for the third quarter of 2016. Cash flow from operating activities for the third quarter of 2017 was $189.1 million, compared to $105.4 million for the third quarter of 2016. Discretionary cash flow (non-GAAP) for the third quarter of 2017 was $207.2 million, compared to $128.4 million for the third quarter of 2016. Free cash flow for the third quarter of 2017 was $4.0 million, compared to $36.7 million for the third quarter of 2016.
Natural gas price realizations, including the impact of derivatives, were $2.03 per thousand cubic feet (Mcf) for the third quarter of 2017, a 16 percent improvement compared to third quarter of 2016. Excluding the impact of derivatives, natural gas price realizations for the quarter were $2.01 per Mcf, representing a $0.99 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $45.53 per barrel (Bbl), an increase of 13 percent compared to the third quarter of 2016. NGL price realizations were $17.04 per Bbl, an increase of 35 percent compared to the third quarter of 2016.
Operating expenses (including financing) decreased to $2.06 per thousand cubic feet equivalent (Mcfe) in the third quarter of 2017, a four percent improvement compared to $2.14 per Mcfe in the third quarter of 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.15 per Mcfe in the third quarter of 2017, a two percent improvement over the third quarter of 2016.
Cabot incurred a total of $175.5 million of capital expenditures during the third quarter of 2017 including $164.9 million of drilling and facilities capital associated with drilling 23 gross (20.4 net) wells and completing 30 gross (22.2 net) wells; $6.3 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $4.3 million of other capital. Additionally, the Company contributed $9.8 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the third quarter of 2017.
See the supplemental table at the end of this press release reconciling the capital expenditures for the quarter.
Year-To-Date 2017 Financial Results
Equivalent production for the nine-month period ended September 30, 2017 was 512.7 Bcfe, consisting of 491.2 Bcf of natural gas, 3,202.8 Mbbls of crude oil and condensate, and 380.6 Mbbls of NGLs.
For the nine-month period ended September 30, 2017, net income was $144.8 million, or $0.31 per share, compared to a net loss of $124.4 million, or $0.27 per share, for the nine-month period ended September 30, 2016. Adjusted net income was $185.1 million, or $0.40 per share, compared to an adjusted net loss of $102.2 million, or $0.23 per share, for the nine-month period ended September 30, 2016. EBITDAX for the nine-month period ended September 30, 2017 was $799.3 million, compared to $368.2 million for the nine-month period ended September 30, 2016. For the nine-month period ended September 30, 2017, cash flow from operations was $719.0 million, compared to $257.7 million for the nine-month period ended September 30, 2016. Discretionary cash flow was $736.0 million for the nine-month period ended September 30, 2017, compared to $297.1 million for the nine-month period ended September 30, 2016. Free cash flow was $125.8 million for the nine-month period ended September 30, 2017, compared to $27.9 million for the nine-month period ended September 30, 2016.
Natural gas price realizations, including the impact of derivatives, were $2.35 per Mcf for the nine-month period ended September 30, 2017, a 45 percent improvement compared to the nine-month period ended September 30, 2016. Oil price realizations, including the impact of derivatives, were $45.70 per Bbl, an increase of 27 percent compared to the nine-month period ended September 30, 2016. NGL price realizations were $18.08 per Bbl, an increase of 63 percent compared to the nine-month period ended September 30, 2016.
Operating expenses (including financing) decreased to $2.03 per Mcfe for the nine-month period ended September 30, 2017, an eight percent improvement compared to $2.21 per Mcfe for the nine-month period ended September 30, 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.14 per Mcfe for the nine-month period ended September 30, 2017, a three percent improvement compared to the nine-month period ended September 30, 2016.
Cabot incurred a total of $582.8 million of capital expenditures during the nine-month period ended September 30, 2017 including $475.2 million of drilling and facilities capital associated with drilling 71 gross (62.5 net) wells and completing 81 gross (70.2 net) wells; $97.8 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $9.8 million of other capital. Additionally, the Company contributed $23.4 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the nine-month period ended September 30, 2017.
Third Quarter 2017 Operational Highlights
Marcellus Shale
During the third quarter of 2017, Cabot averaged 1,706 million cubic feet (Mmcf) per day of net Marcellus production (2,008 gross operated Mmcf per day). During the third quarter, the Company drilled and completed 13.2 net wells and placed 15.2 net wells on production. "We now have 49 fourth generation wells on production and the production data continues to support our 4.4 Bcf per 1,000 lateral feet type curve," noted Dinges. "Additionally, we have placed 12 fifth generation wells on production and the results to date are encouraging with an emphasis on increasing economics by lowering well costs without comprising recoveries."
Cabot is currently operating two rigs and utilizing one 24-hour completion crew in the Marcellus Shale and plans to remain at this level for the remainder of the year.
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the third quarter of 2017 was 15,656 barrels of oil equivalent (Boe) per day (87% oil), an increase of 19 percent sequentially compared to the second quarter of 2017. During the third quarter, the Company drilled 7.2 net wells and completed and placed on production 9.0 net wells. The nine wells placed on production during the quarter had an average lateral length of 10,163 feet, were completed with 1,938 pounds of proppant per foot, and had an average 30-day production rate of approximately 1,040 Boe per day.
Cabot is currently operating one rig and utilizing one 24-hour completion crew in the Eagle Ford Shale. The Company plans to maintain one rig for the remainder of the year and cease its completion activity for the year in mid-November.
Financial Position and Liquidity
As of September 30, 2017, Cabot had total debt of $1.5 billion and cash on hand of $510.3 million. The Company's net debt to adjusted capitalization ratio (non-GAAP) and net debt to last twelve months (LTM) EBITDAX ratio were 27.7 percent and 1.0x, respectively, compared to 28.5 percent and 1.8x as of December 31, 2016.
Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to Cabot. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Fourth Quarter and Full-Year 2017 Guidance Update
Cabot has provided fourth quarter 2017 net production guidance of 1,775 to 1,850 Mmcf per day for natural gas (which reflects the divestiture of the West Virginia properties that closed in the third quarter); 13,250 to 14,250 Bbls per day for crude oil and condensate; and 1,350 to 1,450 Bbls per day for NGLs. "Our wider natural gas production guidance for the fourth quarter reflects the potential for price-related curtailments in the Marcellus due to the unfavorable prices we have witnessed in the daily cash market during the month of October," noted Dinges. "While we anticipate stronger pricing during November and December, we are committed to curtailing a portion of our production if the economics are value-destructive."
Based on the fourth quarter guidance, the Company has tightened its 2017 daily production growth guidance range to 9 - 11 percent. The Company has also reaffirmed its total 2017 program spending of $845 million.
2018 Operating Plan
The Company has initiated its 2018 daily production growth guidance range at 15 to 20 percent (17 to 22 percent pro forma for the West Virginia divestiture). This production growth is based on a capital budget range of $1.025 to $1.150 billion consisting of the following:
Cabot plans to operate three rigs and utilize two completion crews in the Marcellus Shale during 2018. The Company's capital allocation within this guidance range will ultimately be dependent on the timing of completion activity throughout the year, which will be driven by: the Company's outlook for realized natural gas prices; the corresponding level of operating cash flow generated; and the in-service timing of new infrastructure projects. "Our focus is on maximizing margins, returns and free cash flow and we firmly believe the flexibility in our current plan for 2018 will allow us to make the most prudent capital allocation decisions throughout the year in response to evolving market dynamics," commented Dinges.
While the Company's Marcellus growth profile in 2018 is expected to be weighted toward the second half of the year due to the timing of new infrastructure, the 2018 exit production rate is expected to be 35 percent higher than the 2017 Marcellus exit rate. The capital range for the Marcellus in 2018 will position Cabot for Marcellus production growth of 27 to 33 percent in 2019, subject to market conditions and infrastructure timing.
Cabot plans to operate one rig for the full-year and utilize one completion crew for a portion of the year in the Eagle Ford Shale during 2018. The Company's capital allocation within this guidance range will ultimately be dependent on our outlook for realized oil prices. At the current strip, the Company's Eagle Ford program would generate positive free cash flow and generate single-digit oil production growth in 2018.
The Company's exploration budget is comprised of the capital required for testing both exploratory areas during the first half of 2018. If the results from testing during the first half of the year warrant additional activity in the second half of the year, the Company anticipates it would fund the incremental spending with asset sales.
Based on current market indications for commodity prices at the time of this press release, Cabot expects its natural gas price realizations to average $0.45 to $0.50 below NYMEX for the full year of 2018. Based on current strip prices and these differential assumptions, the Company's 2018 program would deliver the following highlights:
Three-Year Marcellus Outlook
Based on the Company's current three-year plan in the Marcellus Shale, Cabot anticipates delivering a three-year Marcellus production compounded annual growth rate (CAGR) from 2017 to 2020 of 20+ percent and a three-year Marcellus discretionary cash flow CAGR of 25+ percent assuming current strip prices (which implies an average realized natural gas price of approximately $2.50 per Mcf during this period). Based on this plan, Cabot's Marcellus asset would generate approximately $2.5 billion of cumulative pre-tax free cash flow from 2018 to 2020 while averaging between $750 and $850 million of annual Marcellus capital expenditures over this period. This plan is subject to market conditions and infrastructure timing and only includes the benefit of our future infrastructure projects that are currently under construction (Atlantic Sunrise pipeline project, Moxie Freedom power generation plant, Lackawanna Energy Center power generation plant, and Tennessee Gas Pipeline's Orion Project).
Capital allocation outside of the Marcellus in 2019 and 2020 will ultimately be dependent on the outlook for oil prices and the outcome of testing in the Company's exploration areas; however, the Company plans to target a self-funding program in the Eagle Ford and utilize asset sales to fund initial asset-level outspend in the exploration areas assuming they are successful.
"We believe that Cabot will deliver top-tier corporate-wide returns, free cash flow generation, and per share growth over the next three years, while returning an increasing amount of capital to our shareholders," highlighted Dinges.
Conference Call Webcast
A conference call is scheduled for Friday, October 27, 2017, at 9:30 a.m. Eastern Time to discuss third quarter 2017 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "target", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
161.2 |
144.4 |
491.2 |
441.8 |
|||||||||||
Crude oil and condensate (Mbbl) |
1,268.0 |
941.4 |
3,202.8 |
3,190.4 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
124.7 |
129.6 |
380.6 |
334.6 |
|||||||||||
Equivalent production (Bcfe) |
169.5 |
150.8 |
512.7 |
463.0 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.03 |
$ |
1.75 |
$ |
2.35 |
$ |
1.62 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.01 |
$ |
1.80 |
$ |
2.35 |
$ |
1.61 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
45.53 |
$ |
40.13 |
$ |
45.70 |
$ |
35.85 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
44.88 |
$ |
40.13 |
$ |
45.13 |
$ |
35.92 |
|||||||
NGL ($/Bbl) |
$ |
17.04 |
$ |
12.64 |
$ |
18.08 |
$ |
11.08 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.15 |
$ |
0.16 |
$ |
0.15 |
$ |
0.17 |
|||||||
Transportation and gathering |
0.70 |
0.70 |
0.71 |
0.70 |
|||||||||||
Taxes other than income |
0.05 |
0.06 |
0.05 |
0.05 |
|||||||||||
Exploration |
0.04 |
0.02 |
0.03 |
0.03 |
|||||||||||
Depreciation, depletion and amortization |
0.86 |
0.93 |
0.83 |
0.96 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.09 |
0.10 |
0.09 |
0.10 |
|||||||||||
Stock-based compensation |
0.05 |
0.03 |
0.05 |
0.05 |
|||||||||||
Interest expense |
0.12 |
0.14 |
0.12 |
0.15 |
|||||||||||
$ |
2.06 |
$ |
2.14 |
$ |
2.03 |
$ |
2.21 |
||||||||
WELLS DRILLED (1) |
|||||||||||||||
Gross |
23 |
11 |
71 |
28 |
|||||||||||
Net |
20.4 |
11.0 |
62.5 |
28.0 |
|||||||||||
WELLS COMPLETED (1) |
|||||||||||||||
Gross |
30 |
23 |
81 |
51 |
|||||||||||
Net |
22.2 |
23.0 |
70.2 |
51.0 |
|||||||||||
(1) Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) |
||||||||||||||||
Quarter Ended |
Nine Months Ended |
|||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 |
||||||||||||
OPERATING REVENUES |
||||||||||||||||
Natural gas |
$ |
323,319 |
$ |
260,200 |
$ |
1,152,089 |
$ |
711,010 |
||||||||
Crude oil and condensate |
56,913 |
37,777 |
144,528 |
114,610 |
||||||||||||
Gain (loss) on derivative instruments |
(836) |
6,904 |
46,353 |
(1,286) |
||||||||||||
Brokered natural gas |
3,528 |
3,641 |
12,260 |
9,417 |
||||||||||||
Other |
2,492 |
1,907 |
8,486 |
5,435 |
||||||||||||
385,416 |
310,429 |
1,363,716 |
839,186 |
|||||||||||||
OPERATING EXPENSES |
||||||||||||||||
Direct operations |
26,282 |
24,626 |
78,185 |
77,139 |
||||||||||||
Transportation and gathering |
117,891 |
105,671 |
361,909 |
322,883 |
||||||||||||
Brokered natural gas |
2,797 |
2,939 |
10,262 |
7,526 |
||||||||||||
Taxes other than income |
9,194 |
8,771 |
26,562 |
23,737 |
||||||||||||
Exploration |
6,466 |
2,988 |
16,623 |
13,109 |
||||||||||||
Depreciation, depletion and amortization |
146,267 |
139,490 |
425,689 |
448,910 |
||||||||||||
Impairment of oil and gas properties |
— |
— |
68,555 |
— |
||||||||||||
General and administrative (excluding stock-based |
||||||||||||||||
compensation) |
15,395 |
14,265 |
44,724 |
44,176 |
||||||||||||
Stock-based compensation(1) |
7,849 |
5,109 |
26,178 |
23,016 |
||||||||||||
332,141 |
303,859 |
1,058,687 |
960,496 |
|||||||||||||
Earnings (loss) on equity method investments |
(1,417) |
(1,727) |
(3,986) |
208 |
||||||||||||
Loss on sale of assets |
(11,872) |
(1,245) |
(13,498) |
(768) |
||||||||||||
INCOME (LOSS) FROM OPERATIONS |
39,986 |
3,598 |
287,545 |
(121,870) |
||||||||||||
Interest expense, net |
20,331 |
21,483 |
61,720 |
67,821 |
||||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
||||||||||||
Other expense (income) |
(5,083) |
402 |
(4,974) |
1,207 |
||||||||||||
Income (loss) before income taxes |
24,738 |
(18,287) |
230,799 |
(195,607) |
||||||||||||
Income tax expense (benefit) |
7,151 |
(8,027) |
85,965 |
(71,243) |
||||||||||||
NET INCOME (LOSS) |
$ |
17,587 |
$ |
(10,260) |
$ |
144,834 |
$ |
(124,364) |
||||||||
Earnings (loss) per share - Basic |
$ |
0.04 |
$ |
(0.02) |
$ |
0.31 |
$ |
(0.27) |
||||||||
Weighted-average common shares outstanding |
462,498 |
465,149 |
464,194 |
454,060 |
||||||||||||
(1) Includes the impact of the Company's performance share awards and restricted stock. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
September 30, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
718,029 |
$ |
715,881 |
|||
Properties and equipment, net (Successful efforts method) |
4,234,772 |
4,250,125 |
|||||
Other assets |
175,965 |
156,563 |
|||||
$ |
5,128,766 |
$ |
5,122,569 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
438,234 |
$ |
257,812 |
|||
Long-term debt, net |
1,284,551 |
1,520,530 |
|||||
Deferred income taxes |
638,014 |
579,447 |
|||||
Other liabilities |
123,373 |
197,113 |
|||||
Stockholders' equity |
2,644,594 |
2,567,667 |
|||||
$ |
5,128,766 |
$ |
5,122,569 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income (loss) |
$ |
17,587 |
$ |
(10,260) |
$ |
144,834 |
$ |
(124,364) |
|||||||
Deferred income tax expense (benefit) |
16,336 |
4,880 |
89,731 |
(59,413) |
|||||||||||
Impairment of oil and gas properties |
— |
— |
68,555 |
— |
|||||||||||
Loss on sale of assets |
11,872 |
1,245 |
13,498 |
768 |
|||||||||||
Exploratory dry hole cost |
— |
— |
2,842 |
18 |
|||||||||||
(Gain) loss on derivative instruments |
836 |
(6,904) |
(46,353) |
1,286 |
|||||||||||
Net cash received in settlement of derivative instruments |
3,906 |
(8,101) |
3,587 |
3,204 |
|||||||||||
Income charges not requiring cash |
156,693 |
147,502 |
459,265 |
475,641 |
|||||||||||
Changes in assets and liabilities |
(18,130) |
(22,947) |
(16,912) |
(39,435) |
|||||||||||
Net cash provided by operating activities |
189,100 |
105,415 |
719,047 |
257,705 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(193,480) |
(85,634) |
(586,813) |
(245,033) |
|||||||||||
Proceeds from sale of assets |
31,236 |
(760) |
32,711 |
49,068 |
|||||||||||
Investment in equity method investments |
(9,756) |
(6,005) |
(23,382) |
(24,176) |
|||||||||||
Net cash used in investing activities |
(172,000) |
(92,399) |
(577,484) |
(220,141) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net borrowings (repayments) of debt |
— |
(20,000) |
— |
(497,000) |
|||||||||||
Treasury stock repurchases |
— |
— |
(68,255) |
— |
|||||||||||
Sale of common stock, net |
— |
— |
— |
995,279 |
|||||||||||
Dividends paid |
(23,125) |
(9,303) |
(55,707) |
(26,885) |
|||||||||||
Tax withholdings on stock award vestings |
(257) |
(10) |
(5,929) |
(5,056) |
|||||||||||
Capitalized debt issuance costs |
— |
— |
— |
(3,223) |
|||||||||||
Other |
4 |
— |
42 |
— |
|||||||||||
Net cash provided by (used in) financing activities |
(23,378) |
(29,313) |
(129,849) |
463,115 |
|||||||||||
Net increase in cash and cash equivalents |
$ |
(6,278) |
$ |
(16,297) |
$ |
11,714 |
$ |
500,679 |
Explanation and Reconciliation of Non-GAAP Financial Measures
The Company reports its financial results in accordance with accounting principles generally accepted in the United States (GAAP). However, the Company believes certain non-GAAP performance measures may provide financial statement users with additional meaningful comparisons between current results, the results of its peers and of prior periods. In addition, the Company believes these measures are used by analysts and others in the valuation, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. See the reconciliations throughout this release of GAAP financial measures to non-GAAP financial measures for the periods indicated.
Management has also included herein certain forward-looking non-GAAP financial measures. Due to the forward-looking nature of these non-GAAP financial measures, management cannot reliably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in capital. Accordingly, the company is unable to present a quantitative reconciliation of such forward-looking non-GAAP financial measures to their most directly comparable forward-looking GAAP financial measures. Reconciling items in future periods could be significant.
Reconciliation of Net Income (Loss) to Adjusted Net Income (Loss) and Adjusted Earnings Per Share
Adjusted Net Income (Loss) and Adjusted Earnings per Share are presented based on management's belief that these non-GAAP measures enable a user of the financial information to understand the impact of these items on reported results. Additionally, this presentation provides a beneficial comparison to similarly adjusted measurements of prior periods. Adjusted Net Income (Loss) and Adjusted Earnings per Share are not measures of financial performance under GAAP and should not be considered as alternatives to net income and earnings per share, as defined by GAAP.
Quarter Ended |
Nine Months Ended | ||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 | |||||||||||
As reported - net income (loss) |
$ |
17,587 |
$ |
(10,260) |
$ |
144,834 |
$ |
(124,364) |
|||||||
Reversal of selected items: |
|||||||||||||||
Impairment of oil and gas properties |
— |
— |
68,555 |
— |
|||||||||||
Loss on sale of assets |
11,872 |
1,245 |
13,498 |
768 |
|||||||||||
(Gain) loss on derivative instruments(1) |
4,742 |
(15,005) |
(42,766) |
4,490 |
|||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
|||||||||||
Drilling rig termination fees |
— |
(1,532) |
— |
1,655 |
|||||||||||
Stock-based compensation expense |
7,849 |
5,109 |
26,178 |
23,016 |
|||||||||||
Severance expense |
3,192 |
57 |
3,192 |
209 |
|||||||||||
OPEB curtailment |
(4,850) |
— |
(4,850) |
— |
|||||||||||
Tax effect on selected items |
(8,427) |
3,675 |
(23,577) |
(12,648) |
|||||||||||
Adjusted net income (loss) |
$ |
31,965 |
$ |
(16,711) |
$ |
185,064 |
$ |
(102,165) |
|||||||
As reported - earnings (loss) per share |
$ |
0.04 |
$ |
(0.02) |
$ |
0.31 |
$ |
(0.27) |
|||||||
Per share impact of selected items |
0.03 |
(0.02) |
0.09 |
0.04 |
|||||||||||
Adjusted earnings (loss) per share |
$ |
0.07 |
$ |
(0.04) |
$ |
0.40 |
$ |
(0.23) |
|||||||
Weighted-average common shares outstanding |
462,498 |
465,149 |
464,194 |
454,060 |
|||||||||||
(1) This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow and Free Cash Flow Calculation and Reconciliation
Discretionary Cash Flow is defined as net cash provided by operating activities excluding changes in assets and liabilities. Discretionary Cash Flow is widely accepted as a financial indicator of an oil and gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary Cash Flow is presented based on management's belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies that use the full cost method of accounting for oil and gas producing activities or have different financing and capital structures or tax rates. Discretionary Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Free Cash Flow is defined as Discretionary Cash Flow (defined above) less capital expenditures and investment in equity method investments. Free Cash Flow is an indicator of a company's ability to generate cash flow after spending the money required to maintain or expand its asset base. Free Cash Flow is presented based on management's belief that this non-GAAP measure is useful information to investors when comparing our cash flows with the cash flows of other companies. Free Cash Flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income.
Quarter Ended |
Nine Months Ended | |||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | ||||||||||||
Net cash provided by operating activities |
$ |
189,100 |
$ |
105,415 |
$ |
719,047 |
$ |
257,705 |
||||||||
Changes in assets and liabilities |
18,130 |
22,947 |
16,912 |
39,435 |
||||||||||||
Discretionary cash flow |
207,230 |
128,362 |
735,959 |
297,140 |
||||||||||||
Capital expenditures |
(193,480) |
(85,634) |
(586,813) |
(245,033) |
||||||||||||
Investment in equity method investments |
(9,756) |
(6,005) |
(23,382) |
(24,176) |
||||||||||||
Free cash flow |
$ |
3,994 |
$ |
36,723 |
$ |
125,764 |
$ |
27,931 |
EBITDAX Calculation and Reconciliation
EBITDAX is defined as net income plus loss on debt extinguishment, interest expense, other expense, income tax expense, depreciation, depletion and amortization (including impairments), exploration expense, gain and loss on sale of assets, non-cash gain and loss on derivative instruments, loss on equity method investments, and stock-based compensation expense. EBITDAX is presented based on management's belief that this non-GAAP measure is useful information to investors when evaluating our ability to internally fund exploration and development activities and to service or incur debt without regard to financial or capital structure. EBITDAX is not a measure of financial performance under GAAP and should not be considered as alternative to cash flows from operating activities or net income, as defined by GAAP, or as a measure of liquidity.
Quarter Ended |
Nine Months Ended | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
Net income (loss) |
$ |
17,587 |
$ |
(10,260) |
$ |
144,834 |
$ |
(124,364) |
|||||||
Plus (less): |
|||||||||||||||
Loss on debt extinguishment |
— |
— |
— |
4,709 |
|||||||||||
Interest expense, net |
20,331 |
21,483 |
61,720 |
67,821 |
|||||||||||
Other expense (income) |
(5,083) |
402 |
(4,974) |
1,207 |
|||||||||||
Income tax expense (benefit) |
7,151 |
(8,027) |
85,965 |
(71,243) |
|||||||||||
Depreciation, depletion and amortization |
146,267 |
139,490 |
425,689 |
448,910 |
|||||||||||
Impairment of oil and gas properties |
— |
— |
68,555 |
— |
|||||||||||
Exploration |
6,466 |
2,988 |
16,623 |
13,109 |
|||||||||||
Loss on sale of assets |
11,872 |
1,245 |
13,498 |
768 |
|||||||||||
Non-cash (gain) loss on derivative instruments |
4,742 |
(15,005) |
(42,766) |
4,490 |
|||||||||||
(Earnings) loss on equity method investments |
1,417 |
1,727 |
3,986 |
(208) |
|||||||||||
Stock-based compensation |
7,849 |
5,109 |
26,178 |
23,016 |
|||||||||||
EBITDAX |
$ |
218,599 |
$ |
139,152 |
$ |
799,308 |
$ |
368,215 |
Net Debt Reconciliation
The total debt to total capitalization ratio is calculated by dividing total debt by the sum of total debt and total stockholders' equity. This ratio is a measurement which is presented in our annual and interim filings and management believes this ratio is useful to investors in determining the Company's leverage. Net Debt is calculated by subtracting cash and cash equivalents from total debt. Net Debt and the Net Debt to Total Capitalization ratio are non-GAAP measures which management believes are also useful to investors since the Company has the ability to and may decide to use a portion of its cash and cash equivalents to retire debt. Additionally, as the Company may incur additional expenditures without increasing debt, it is appropriate to apply cash and cash equivalents to debt in calculating the Net Debt to Total Capitalization ratio.
(In thousands) |
September 30, |
December 31, | |||||
Current portion of long-term debt |
$ |
237,000 |
$ |
— |
|||
Long-term debt, net |
1,284,551 |
1,520,530 |
|||||
Total debt |
$ |
1,521,551 |
$ |
1,520,530 |
|||
Stockholders' equity |
2,644,594 |
2,567,667 |
|||||
Total capitalization |
$ |
4,166,145 |
$ |
4,088,197 |
|||
Total debt |
$ |
1,521,551 |
$ |
1,520,530 |
|||
Less: Cash and cash equivalents |
(510,256) |
(498,542) |
|||||
Net debt |
$ |
1,011,295 |
$ |
1,021,988 |
|||
Net debt |
$ |
1,011,295 |
$ |
1,021,988 |
|||
Stockholders' equity |
2,644,594 |
2,567,667 |
|||||
Total adjusted capitalization |
$ |
3,655,889 |
$ |
3,589,655 |
|||
Total debt to total capitalization ratio |
36.5 |
% |
37.2 |
% | |||
Less: Impact of cash and cash equivalents |
8.8 |
% |
8.7 |
% | |||
Net debt to adjusted capitalization ratio |
27.7 |
% |
28.5 |
% |
Capital Expenditures | ||||||||||||||||
Quarter Ended |
Nine Months Ended | |||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | ||||||||||||
Cash paid for capital expenditures |
$ |
193,480 |
$ |
85,634 |
$ |
586,813 |
$ |
245,033 |
||||||||
Change in accrued capital costs |
(18,005) |
13,905 |
(1,207) |
17,072 |
||||||||||||
Exploratory dry hole cost |
— |
— |
(2,842) |
(18) |
||||||||||||
Capital expenditures |
$ |
175,475 |
$ |
99,539 |
$ |
582,764 |
$ |
262,087 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-third-quarter-2017-results-provides-2018-operating-plan-and-three-year-marcellus-shale-outlook-300544722.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 25, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of five cents ($0.05) per share on the Company's common stock. The dividend will be paid November 17, 2017 to all shareholders of record as of the close of business November 8, 2017.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300543562.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 2, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its third quarter 2017 earnings conference call on Friday, October 27, 2017 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-third-quarter-2017-earnings-release-date-and-conference-call-300529331.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Aug. 15, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced the election of Ms. Amanda M. Brock and Mr. Marcus A. Watts to its Board of Directors, effective immediately. The addition of Ms. Brock and Mr. Watts to the Board will bring the total to eight directors, with seven qualifying as independent directors.
Ms. Brock has been the Chief Executive Officer of Water Standard, a water treatment company focused on water-based enhanced oil recovery, recycling and reuse of water and produced water treatment. Ms. Brock joined the company at inception in 2009. Ms. Brock is also working with Solaris Midstream which is developing integrated water infrastructure systems and midstream assets in key oil and gas basins in the US. Ms. Brock served as Executive Director and President, Americas, of Azurix, a global water treatment and services company, from 1999-2002. Prior to that, she worked for Enron Corp. in various capacities from 1991, including President of a division responsible for the management of power plants, related assets and joint ventures worldwide. Ms. Brock has received numerous professional awards, including being named one of the top 25 people globally in water and wastewater in 2016 by Water and Wastewater International and as a Houston Bar Journal honoree for Women in Energy in 2016. Ms. Brock has a law degree from Louisiana State University where she was also recognized as an under 40 Alumni, and began her career as an attorney for the law firm of Vinson & Elkins.
Mr. Watts is President of The Friedkin Group, an umbrella company overseeing various business interests that are principally automotive-related, including a wholesale distributor of Toyota vehicles and products. Prior to joining The Friedkin Group, Mr. Watts was an attorney with the international law firm of Locke Lord LLP, with over 26 years of experience in corporate and securities law, governance and related matters. Mr. Watts served as the Managing Partner of the Houston, Texas office and Vice-Chairman of the firm-wide Executive Committee. Mr. Watts served as a director of Complete Production Services until its merger with Superior Energy Services in 2012 and currently serves on the Board of directors of Service Corporation International. Mr. Watts holds a law degree from Harvard Law School and a B.S. degree from Texas A&M University.
"As we continue to refresh our Board, we are extremely pleased to announce the addition of these two exceptional individuals with very diverse backgrounds and experience to complement the deep skill set we have in place on our Board," stated Dan O. Dinges, Chairman, President and Chief Executive Officer. "Amanda brings an expertise in water management, treatment and recycling to the Board at a time when those issues are becoming increasingly important to our Company and Marc adds a keen legal mind and over 26 years of experience in corporate, transactional and public company governance to our Board." Dinges adds, "We are very fortunate to be able to welcome both of these outstanding directors."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-new-directors-300504807.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 27, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second quarter of 2017.
Second Quarter 2017 Highlights
"Our second quarter results demonstrate what our high-quality asset base can continue to deliver, highlighted by double-digit year-over-year production growth while generating positive free cash flow for the fifth consecutive quarter," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "We continue to focus our capital allocation efforts not only on driving returns-focused growth from our deep inventory base, but also on increasing our return of capital to shareholders as evidenced by our dividend increase and share repurchases during the quarter. Year-to-date we have returned over $100 million of our free cash flow to shareholders."
Second Quarter 2017 Financial Results
Equivalent production for the second quarter of 2017 was 173.1 billion cubic feet equivalent (Bcfe), consisting of 166.2 billion cubic feet (Bcf) of natural gas, 1,014.0 thousand barrels (Mbbls) of crude oil and condensate, and 132.4 Mbbls of natural gas liquids (NGLs).
Net income for the second quarter of 2017 was $21.5 million, or $0.05 per share, compared to a net loss of $62.9 million, or $0.14 per share, for the second quarter of 2016. Net income for the second quarter of 2017 included the impact of a non-cash, after-tax impairment charge of $43.2 million primarily associated with non-core oil and gas properties and related pipeline assets in West Virginia, Virginia and Ohio that were classified as held for sale as of June 30, 2017. Excluding the effect of this impairment and other selected items (detailed in the supplemental table below), net income was $64.0 million, or $0.14 per share, compared to a net loss of $30.2 million, or $0.07 per share, for the second quarter of 2016. Cash flow from operating activities for the second quarter of 2017 was $260.6 million, compared to $85.2 million for the second quarter of 2016. Discretionary cash flow for the second quarter of 2017 was $255.7 million, compared to $97.6 million for the second quarter of 2016. EBITDAX for the second quarter of 2017 was $274.4 million, compared to $127.6 million for the second quarter of 2016. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $2.38 per thousand cubic feet (Mcf) for the second quarter of 2017, a 46 percent improvement compared to second quarter of 2016. The Company's natural gas price realizations for the quarter represented an $0.80 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $44.96 per barrel (Bbl), an increase of 12 percent compared to the second quarter of 2016. NGL price realizations were $16.59 per Bbl, an increase of 33 percent compared to the second quarter of 2016.
Operating expenses (including financing) decreased to $2.02 per thousand cubic feet equivalent (Mcfe) in the second quarter of 2017, a nine percent improvement compared to $2.22 per Mcfe in the second quarter of 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.12 per Mcfe in the second quarter of 2017, a six percent improvement over the second quarter of 2016.
Cabot incurred a total of $195.1 million of capital expenditures during the second quarter of 2017 including $168.3 million of drilling and facilities capital associated with drilling 27 gross (21.1 net) wells and completing 26 gross (24.0 net) wells; $23.6 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $3.2 million of other capital. Additionally, the Company contributed $5.9 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the second quarter of 2017.
See the supplemental table at the end of this press release reconciling the capital expenditures for the quarter.
Year-To-Date 2017 Financial Results
Equivalent production for the six-month period ended June 30, 2017 was 343.1 Bcfe, consisting of 330.0 Bcf of natural gas, 1,934.6 Mbbls of crude oil and condensate, and 255.9 Mbbls of NGLs.
For the six-month period ended June 30, 2017, net income was $127.2 million, or $0.27 per share, compared to a net loss of $114.1 million, or $0.25 per share, for the six-month period ended June 30, 2016. Excluding the effect of selected items (detailed in the supplemental table below), net income was $153.1 million, or $0.33 per share, compared to a net loss of $85.6 million, or $0.19 per share, for the six-month period ended June 30, 2016. For the six-month period ended June 30, 2017, cash flow from operations was $529.9 million, compared to $152.3 million for the six-month period ended June 30, 2016. Discretionary cash flow was $528.7 million for the six-month period ended June 30, 2017, compared to $168.8 million for the six-month period ended June 30, 2016. EBITDAX for the six-month period ended June 30, 2017 was $580.7 million, compared to $229.1 million for the six-month period ended June 30, 2016.
Natural gas price realizations, including the impact of derivatives, were $2.51 per Mcf for the six-month period ended June 30, 2017, a 62 percent improvement compared to the six-month period ended June 30, 2016. Oil price realizations, including the impact of derivatives, were $45.80 per Bbl, an increase of 34 percent compared to the six-month period ended June 30, 2016. NGL price realizations were $18.58 per Bbl, an increase of 84 percent compared to the six-month period ended June 30, 2016.
Operating expenses (including financing) decreased to $2.01 per Mcfe for the six-month period ended June 30, 2017, a 10 percent improvement compared to $2.24 per Mcfe for the six-month period ended June 30, 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.13 per Mcfe for the six-month period ended June 30, 2017, a four percent improvement compared to the six-month period ended June 30, 2016.
Cabot incurred a total of $407.3 million of capital expenditures during the six-month period ended June 30, 2017 including $310.3 million of drilling and facilities capital associated with drilling 48 gross (42.1 net) wells and completing 51 gross (48.0 net) wells; $91.5 million of leasehold acquisition capital primarily associated with the Company's grassroots leasing efforts in two new exploratory operating areas; and $5.5 million of other capital. Additionally, the Company contributed $13.6 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the six-month period ended June 30, 2017.
Second Quarter 2017 Operational Highlights
Marcellus Shale
During the second quarter of 2017, Cabot averaged 1,771 million cubic feet (Mmcf) per day of net Marcellus production (2,079 gross operated Mmcf per day). During the second quarter, the Company drilled 13.7 net wells, completed 8.0 net wells and placed 6.0 net wells on production. "The average cumulative production for the 26 fourth generation wells that we placed on production during the first half of 2017 continues to outperform our 4.4 Bcf per 1,000 lateral feet type curve," noted Dinges.
Cabot is currently operating two rigs and utilizing one 24-hour completion crew in the Marcellus Shale and plans to remain at this level for the remainder of the year.
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the second quarter of 2017 was 13,146 barrels of oil equivalent (Boe) per day (84% oil), an increase of nine percent sequentially compared to the first quarter of 2017. During the second quarter, the Company drilled 7.4 net wells and completed and placed on production 16.0 net wells. "Despite lower oil production volumes than originally anticipated for the quarter primarily due to operational delays and an extended clean up period for our longer lateral wells, we are confident that we will generate double-digit oil production growth for the year," commented Dinges.
Cabot is currently operating one rig and utilizing one 24-hour completion crew in the Eagle Ford Shale. The Company plans to maintain one rig for the remainder of the year and cease its completion activity for the year in October.
Share Repurchase Program Update
During the second quarter of 2017, Cabot repurchased 3.0 million shares at a weighted-average share price of $22.41. The Company has approximately 7.1 million shares remaining under its share repurchase program. "We will remain opportunistic with our share repurchase program as we continue to become more confident in the timing of infrastructure additions and the resulting increased level of positive free cash flow that we are anticipating in the coming years," stated Dinges.
Non-Core Asset Sale
During the second quarter of 2017, the Company entered into a purchase and sale agreement to sell certain legacy conventional oil and gas properties located in West Virginia, Virginia and Ohio for $41.3 million, subject to customary purchase price adjustments. Year-to-date 2017 production from these properties was 38.8 million cubic feet equivalent (Mmcfe) per day (99% gas). This transaction is expected to close by the end of the third quarter of 2017. Cabot will retain the deep rights across this approximately 780,000 net acre position. "Since we first began leasing in the Marcellus Shale in 2006, we have made efforts to high-grade our portfolio by opportunistically monetizing non-core assets and focusing our drilling activity in our lower-cost assets," said Dinges. "We have not allocated drilling capital to this legacy asset position since 2009 and had no plans to allocate capital to these assets in the future given our substantial drilling inventory in the Marcellus and Eagle Ford and our increased focus on returning capital to shareholders."
Financial Position and Liquidity
As of June 30, 2017, Cabot had total debt of $1.5 billion and cash on hand of $516.5 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 27.6 percent and 1.1x, respectively, compared to 28.5 percent and 1.8x as of December 31, 2016.
Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to Cabot. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Third Quarter and Full-Year 2017 Guidance Update
Cabot has provided third quarter 2017 net production guidance of 1,750 to 1,800 Mmcf per day for natural gas; 13,000 to 13,750 Bbls per day for crude oil and condensate; and 1,350 to 1,450 Bbls per day for NGLs. "The mid-point of our natural gas production guidance for the third quarter implies a three percent sequential decline relative to the second quarter primarily due to mechanical issues at a third-party compressor station that began in late June and are expected to continue until late August; however, we anticipate sequential growth of natural gas volumes in the fourth quarter," noted Dinges.
The Company has reaffirmed its 2017 production growth guidance range of 8 - 12 percent (including 10 - 15 percent oil production growth) and its total 2017 program spending of $845 million, which is comprised of $775 million of exploration and production (E&P) spending and $70 million of contributions to its equity pipeline investments.
For further disclosure on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast
A conference call is scheduled for Friday, July 28, 2017, at 9:30 a.m. Eastern Time to discuss second quarter 2017 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "target", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
OPERATING DATA | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
166.2 |
144.3 |
330.0 |
297.4 |
|||||||||||
Crude oil and condensate (Mbbl) |
1,014.0 |
1,139.3 |
1,934.6 |
2,248.9 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
132.4 |
112.9 |
255.9 |
205.0 |
|||||||||||
Equivalent production (Bcfe) |
173.1 |
151.8 |
343.1 |
312.1 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.38 |
$ |
1.63 |
$ |
2.51 |
$ |
1.55 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.38 |
$ |
1.55 |
$ |
2.51 |
$ |
1.52 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
44.96 |
$ |
40.30 |
$ |
45.80 |
$ |
34.06 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
44.03 |
$ |
40.51 |
$ |
45.29 |
$ |
34.16 |
|||||||
NGL ($/Bbl) |
$ |
16.59 |
$ |
12.43 |
$ |
18.58 |
$ |
10.09 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.16 |
$ |
0.17 |
$ |
0.15 |
$ |
0.17 |
|||||||
Transportation and gathering |
0.70 |
0.71 |
0.71 |
0.70 |
|||||||||||
Taxes other than income |
0.05 |
0.06 |
0.05 |
0.05 |
|||||||||||
Exploration |
0.02 |
0.02 |
0.03 |
0.03 |
|||||||||||
Depreciation, depletion and amortization |
0.83 |
0.97 |
0.81 |
0.99 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.08 |
0.09 |
0.09 |
0.10 |
|||||||||||
Stock-based compensation |
0.06 |
0.05 |
0.05 |
0.06 |
|||||||||||
Interest expense |
0.12 |
0.14 |
0.12 |
0.15 |
|||||||||||
$ |
2.02 |
$ |
2.22 |
$ |
2.01 |
$ |
2.24 |
||||||||
WELLS DRILLED (1) |
|||||||||||||||
Gross |
27 |
7 |
48 |
17 |
|||||||||||
Net |
21.1 |
7.0 |
42.1 |
17.0 |
|||||||||||
WELLS COMPLETED (1) |
|||||||||||||||
Gross |
26 |
13 |
51 |
28 |
|||||||||||
Net |
24.0 |
13.0 |
48.0 |
28.0 |
|||||||||||
(1) Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 | |||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
395,328 |
$ |
223,232 |
$ |
828,770 |
$ |
450,811 |
|||||||
Crude oil and condensate |
44,625 |
46,156 |
87,616 |
76,833 |
|||||||||||
Gain (loss) on derivative instruments |
13,805 |
(27,184) |
47,190 |
(8,190) |
|||||||||||
Brokered natural gas |
4,037 |
2,596 |
8,732 |
5,776 |
|||||||||||
Other |
2,662 |
2,016 |
5,994 |
3,527 |
|||||||||||
460,457 |
246,816 |
978,302 |
528,757 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
27,262 |
26,477 |
51,903 |
52,513 |
|||||||||||
Transportation and gathering |
120,544 |
107,560 |
244,018 |
217,213 |
|||||||||||
Brokered natural gas |
3,419 |
2,021 |
7,465 |
4,587 |
|||||||||||
Taxes other than income |
8,310 |
8,973 |
17,368 |
14,967 |
|||||||||||
Exploration |
3,959 |
3,738 |
10,157 |
10,121 |
|||||||||||
Depreciation, depletion and amortization |
144,322 |
147,533 |
279,422 |
309,420 |
|||||||||||
Impairment of oil and gas properties |
68,555 |
— |
68,555 |
— |
|||||||||||
General and administrative (excluding stock-based compensation) |
13,882 |
12,644 |
29,331 |
29,911 |
|||||||||||
Stock-based compensation(1) |
10,075 |
7,301 |
18,328 |
17,906 |
|||||||||||
400,328 |
316,247 |
726,547 |
656,638 |
||||||||||||
Earnings (loss) on equity method investments |
(1,286) |
(73) |
(2,569) |
1,935 |
|||||||||||
Gain (loss) on sale of assets |
(1,403) |
(878) |
(1,626) |
477 |
|||||||||||
INCOME (LOSS) FROM OPERATIONS |
57,440 |
(70,382) |
247,560 |
(125,469) |
|||||||||||
Interest expense |
20,619 |
21,963 |
41,390 |
46,338 |
|||||||||||
Loss on debt extinguishment |
— |
4,709 |
— |
4,709 |
|||||||||||
Other (income) expense |
(315) |
302 |
109 |
804 |
|||||||||||
Income (loss) before income taxes |
37,136 |
(97,356) |
206,061 |
(177,320) |
|||||||||||
Income tax expense (benefit) |
15,609 |
(34,446) |
78,814 |
(63,216) |
|||||||||||
NET INCOME (LOSS) |
$ |
21,527 |
$ |
(62,910) |
$ |
127,247 |
$ |
(114,104) |
|||||||
Earnings (loss) per share - Basic |
$ |
0.05 |
$ |
(0.14) |
$ |
0.27 |
$ |
(0.25) |
|||||||
Weighted-average common shares outstanding |
464,768 |
465,068 |
465,057 |
448,455 |
|||||||||||
(1) Includes the impact of the Company's performance share awards, restricted stock and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
June 30, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
735,824 |
$ |
715,881 |
|||
Properties and equipment, net (Successful efforts method) |
4,202,985 |
4,250,125 |
|||||
Other assets |
280,650 |
156,563 |
|||||
$ |
5,219,459 |
$ |
5,122,569 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
234,422 |
$ |
257,812 |
|||
Long-term debt, net |
1,521,211 |
1,520,530 |
|||||
Deferred income taxes |
617,332 |
579,447 |
|||||
Other liabilities |
204,463 |
197,113 |
|||||
Stockholders' equity |
2,642,031 |
2,567,667 |
|||||
$ |
5,219,459 |
$ |
5,122,569 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income (loss) |
$ |
21,527 |
$ |
(62,910) |
$ |
127,247 |
$ |
(114,104) |
|||||||
Deferred income tax expense (benefit) |
20,104 |
(35,322) |
73,394 |
(64,294) |
|||||||||||
Impairment of oil and gas properties |
68,555 |
— |
68,555 |
— |
|||||||||||
(Gain) loss on sale of assets |
1,403 |
878 |
1,626 |
(477) |
|||||||||||
Exploratory dry hole cost |
— |
18 |
2,842 |
18 |
|||||||||||
(Gain) loss on derivative instruments |
(13,805) |
27,184 |
(47,190) |
8,190 |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
1,204 |
11,305 |
(319) |
11,305 |
|||||||||||
Income charges not requiring cash |
156,719 |
156,465 |
302,573 |
328,140 |
|||||||||||
Changes in assets and liabilities |
4,861 |
(12,440) |
1,218 |
(16,488) |
|||||||||||
Net cash provided by operating activities |
260,568 |
85,178 |
529,946 |
152,290 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(184,949) |
(67,162) |
(393,333) |
(159,399) |
|||||||||||
Proceeds from sale of assets |
1,101 |
— |
1,475 |
49,828 |
|||||||||||
Investment in equity method investments |
(5,884) |
(6,519) |
(13,626) |
(18,171) |
|||||||||||
Net cash used in investing activities |
(189,732) |
(73,681) |
(405,484) |
(127,742) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net borrowings (repayments) of debt |
— |
(64,000) |
— |
(477,000) |
|||||||||||
Treasury stock repurchases |
(68,255) |
— |
(68,255) |
— |
|||||||||||
Sale of common stock, net |
— |
1 |
— |
995,279 |
|||||||||||
Dividends paid |
(23,276) |
(9,300) |
(32,582) |
(17,582) |
|||||||||||
Tax withholdings on stock award vestings |
(258) |
(24) |
(5,672) |
(5,046) |
|||||||||||
Capitalized debt issuance costs |
— |
— |
— |
(3,223) |
|||||||||||
Other |
2 |
— |
39 |
— |
|||||||||||
Net cash provided by (used in) financing activities |
(91,787) |
(73,323) |
(106,470) |
492,428 |
|||||||||||
Net increase in cash and cash equivalents |
$ |
(20,951) |
$ |
(61,826) |
$ |
17,992 |
$ |
516,976 |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands, except per share amounts) |
2017 |
2016 |
2017 |
2016 | |||||||||||
As reported - net income (loss) |
$ |
21,527 |
$ |
(62,910) |
$ |
127,247 |
$ |
(114,104) |
|||||||
Reversal of selected items: |
|||||||||||||||
Impairment of oil and gas properties |
68,555 |
— |
68,555 |
— |
|||||||||||
(Gain) loss on sale of assets |
1,403 |
878 |
1,626 |
(477) |
|||||||||||
(Gain) loss on derivative instruments(1) |
(12,601) |
38,489 |
(47,509) |
19,495 |
|||||||||||
Loss on debt extinguishment |
— |
4,709 |
— |
4,709 |
|||||||||||
Drilling rig termination fees |
— |
— |
— |
3,188 |
|||||||||||
Stock-based compensation expense |
10,075 |
7,301 |
18,328 |
17,906 |
|||||||||||
Tax effect on selected items |
(24,916) |
(18,647) |
(15,150) |
(16,268) |
|||||||||||
Net income (loss) excluding selected items |
$ |
64,043 |
$ |
(30,180) |
$ |
153,097 |
$ |
(85,551) |
|||||||
As reported - earnings (loss) per share |
$ |
0.05 |
$ |
(0.14) |
$ |
0.27 |
$ |
(0.25) |
|||||||
Per share impact of selected items |
0.09 |
0.07 |
0.06 |
0.06 |
|||||||||||
Earnings (loss) per share excluding selected items |
$ |
0.14 |
$ |
(0.07) |
$ |
0.33 |
$ |
(0.19) |
|||||||
Weighted-average common shares outstanding |
464,768 |
465,068 |
465,057 |
448,455 |
|||||||||||
(1) This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
Net income (loss) |
$ |
21,527 |
$ |
(62,910) |
$ |
127,247 |
$ |
(114,104) |
|||||||
Plus (less): |
|||||||||||||||
Deferred income tax expense (benefit) |
20,104 |
(35,322) |
73,394 |
(64,294) |
|||||||||||
Impairment of oil and gas properties |
68,555 |
— |
68,555 |
— |
|||||||||||
(Gain) loss on sale of assets |
1,403 |
878 |
1,626 |
(477) |
|||||||||||
Exploratory dry hole cost |
— |
18 |
2,842 |
18 |
|||||||||||
(Gain) loss on derivative instruments |
(13,805) |
27,184 |
(47,190) |
8,190 |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
1,204 |
11,305 |
(319) |
11,305 |
|||||||||||
Income charges not requiring cash |
156,719 |
156,465 |
302,573 |
328,140 |
|||||||||||
Discretionary cash flow |
255,707 |
97,618 |
528,728 |
168,778 |
|||||||||||
Changes in assets and liabilities |
4,861 |
(12,440) |
1,218 |
(16,488) |
|||||||||||
Net cash provided by operating activities |
$ |
260,568 |
$ |
85,178 |
$ |
529,946 |
$ |
152,290 |
EBITDAX Calculation and Reconciliation | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | |||||||||||
Net income (loss) |
$ |
21,527 |
$ |
(62,910) |
$ |
127,247 |
$ |
(114,104) |
|||||||
Plus (less): |
|||||||||||||||
Loss on debt extinguishment |
— |
4,709 |
— |
4,709 |
|||||||||||
Interest expense |
20,619 |
21,963 |
41,390 |
46,338 |
|||||||||||
Other (income) expense |
(315) |
302 |
109 |
804 |
|||||||||||
Income tax expense (benefit) |
15,609 |
(34,446) |
78,814 |
(63,216) |
|||||||||||
Depreciation, depletion and amortization |
144,322 |
147,533 |
279,422 |
309,420 |
|||||||||||
Impairment of oil and gas properties |
68,555 |
— |
68,555 |
— |
|||||||||||
Exploration |
3,959 |
3,738 |
10,157 |
10,121 |
|||||||||||
(Gain) loss on sale of assets |
1,403 |
878 |
1,626 |
(477) |
|||||||||||
Non-cash (gain) loss on derivative instruments |
(12,601) |
38,489 |
(47,509) |
19,495 |
|||||||||||
(Earnings) loss on equity method investments |
1,286 |
73 |
2,569 |
(1,935) |
|||||||||||
Stock-based compensation |
10,075 |
7,301 |
18,328 |
17,906 |
|||||||||||
EBITDAX |
$ |
274,439 |
$ |
127,630 |
$ |
580,708 |
$ |
229,061 |
Net Debt Reconciliation | |||||||
(In thousands) |
June 30, |
December 31, | |||||
Total debt |
$ |
1,521,211 |
$ |
1,520,530 |
|||
Stockholders' equity |
2,642,031 |
2,567,667 |
|||||
Total capitalization |
$ |
4,163,242 |
$ |
4,088,197 |
|||
Total debt |
$ |
1,521,211 |
$ |
1,520,530 |
|||
Less: Cash and cash equivalents |
(516,534) |
(498,542) |
|||||
Net debt |
$ |
1,004,677 |
$ |
1,021,988 |
|||
Net debt |
$ |
1,004,677 |
$ |
1,021,988 |
|||
Stockholders' equity |
2,642,031 |
2,567,667 |
|||||
Total adjusted capitalization |
$ |
3,646,708 |
$ |
3,589,655 |
|||
Total debt to total capitalization ratio |
36.5 |
% |
37.2 |
% | |||
Less: Impact of cash and cash equivalents |
8.9 |
% |
8.7 |
% | |||
Net debt to adjusted capitalization ratio |
27.6 |
% |
28.5 |
% |
Capital Expenditures | ||||||||||||||||
Quarter Ended |
Six Months Ended | |||||||||||||||
(In thousands) |
2017 |
2016 |
2017 |
2016 | ||||||||||||
Cash paid for capital expenditures |
$ |
184,949 |
$ |
67,162 |
$ |
393,333 |
$ |
159,399 |
||||||||
Change in accrued capital costs |
10,103 |
3,716 |
16,798 |
3,167 |
||||||||||||
Exploratory dry hole cost |
— |
(18) |
(2,842) |
(18) |
||||||||||||
Capital expenditures |
$ |
195,052 |
$ |
70,860 |
$ |
407,289 |
$ |
162,548 |
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-announces-second-quarter-2017-results-300495845.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 27, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of five cents ($0.05) per share on the Company's common stock. The dividend will be paid August 24, 2017 to all shareholders of record as of the close of business August 10, 2017.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
View original content:http://www.prnewswire.com/news-releases/cabot-oil--gas-corporation-declares-dividend-300495605.html
SOURCE Cabot Oil & Gas Corporation
HOUSTON, June 30, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its second quarter 2017 earnings conference call on Friday, July 28, 2017 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, May 3, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a 150 percent increase in its regular quarterly dividend to five cents ($0.05) per share on the Company's common stock. The dividend will be paid on May 31, 2017 to all shareholders of record as of the close of business on May 17, 2017.
"With the momentum of our Marcellus operations from both the macro commodity and pipeline infrastructure outlooks, along with our expectation for continued positive free cash flow generation, our Board agreed with management's recommendation to increase the dividend," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "Last week on our conference call I reviewed our uses for free cash flow highlighting returning cash to shareholders as an important consideration under our plan. Today marks a first step."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 28, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the first quarter of 2017.
First Quarter 2017 Highlights
"Our significant increase in net income and cash flow for the quarter highlights the impact of higher realized natural gas prices due to the recent tightening of the U.S. natural gas market," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "Based on our improved outlook for natural gas price realizations throughout the year, we have increased our production guidance range to reflect our confidence in delivering a higher level of returns-focused growth in 2017."
First Quarter 2017 Financial Results
Equivalent production for the first quarter of 2017 was 170.1 billion cubic feet equivalent (Bcfe), consisting of 163.8 billion cubic feet (Bcf) of natural gas, 921.0 thousand barrels (Mbbls) of crude oil and condensate, and 123.5 Mbbls of natural gas liquids (NGLs). Equivalent daily production was in line with the high-end of the Company's guidance range for the quarter.
Net income for the first quarter of 2017 was $105.7 million, or $0.23 per share, compared to a net loss of $51.2 million, or $0.12 per share, for the first quarter of 2016. Excluding the effect of selected items (detailed in the table below), net income was $89.1 million, or $0.19 per share, compared to a net loss of $55.4 million, or $0.13 per share, for the first quarter of 2016. Cash flow from operating activities for the first quarter of 2017 was $269.4 million, compared to $67.1 million for the first quarter of 2016. Discretionary cash flow for the first quarter of 2017 was $273.0 million, compared to $71.2 million for the first quarter of 2016. EBITDAX for the first quarter of 2017 was $306.3 million, compared to $101.4 million for the first quarter of 2016. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $2.64 per thousand cubic feet (Mcf) for the first quarter of 2017, a 77 percent improvement compared to first quarter of 2016 and a 36 percent sequential improvement compared to the fourth quarter of 2016. Excluding the impact of derivatives, natural gas price realizations for the quarter were $2.65 per Mcf, representing a $0.67 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $46.73 per barrel (Bbl), an increase of 69 percent compared to the first quarter of 2016. NGL price realizations were $20.71 per Bbl, an increase of 187 percent compared to the first quarter of 2016.
Operating expenses (including financing) decreased to $2.01 per thousand cubic feet equivalent (Mcfe) in the first quarter of 2017, an 11 percent improvement compared to $2.26 per Mcfe in the first quarter of 2016. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.15 per Mcfe in the first quarter of 2017, a two percent improvement over the first quarter of 2016. All operating expense categories decreased on a per unit basis relative to last year's comparable quarter except for transportation and gathering, which increased primarily as a result of a charge associated with transportation expenses in the Eagle Ford, and taxes other than income, which increased primarily as a result of higher crude oil prices and the receipt of a production tax refund in the first quarter of 2016. The Company has reaffirmed its cost guidance for the full-year.
Cabot incurred a total of $212.2 million of capital expenditures during the first quarter of 2017 including $142.0 million of drilling and facilities capital associated with drilling 21 gross (21.0 net) wells and completing 25 gross (24.0 net) wells; $67.9 million of leasehold acquisition capital associated with grassroots leasing efforts, primarily in new exploratory operating areas; and $2.4 million of other capital. Additionally, the Company contributed $7.7 million to its equity pipeline investments in the Atlantic Sunrise and Constitution projects during the first quarter of 2017. "Recently, we have highlighted our plans to evaluate new platforms for future growth that generate competitive full-cycle returns," stated Dinges. "While this is not an easy task, we have identified two new exploratory areas where we have the potential to build sizable, contiguous acreage positions at a low cost of entry that have garnered investment capital in a similar manner as our Marcellus asset did over ten years ago." Added Dinges, "As we have demonstrated over the years, we will continue to remain disciplined with our capital as we assess these new opportunities."
See the supplemental table at the end of this press release reconciling the capital expenditures for the quarter.
First Quarter 2017 Operational Highlights
Marcellus Shale
During the first quarter of 2017, Cabot averaged 1,782 million cubic feet (Mmcf) per day of net Marcellus production (2,088 gross operated Mmcf per day), an increase of six percent sequentially compared to the fourth quarter of 2016. During the first quarter, the Company drilled and completed 14 net wells and placed 23 net wells on production. "20 of the wells placed on production during the quarter were completed with our fourth generation completion design and the average cumulative production for these wells is outperforming our 4.4 Bcf per 1,000 lateral feet type curve," commented Dinges.
Cabot's operating efficiencies in the Marcellus Shale continue to improve, highlighted by another record-low quarter for drilling costs per foot, which were 12 percent lower in the first quarter of 2017 as compared to the full-year 2016 average.
Cabot is currently operating two rigs and utilizing one 24-hour completion crew in the Marcellus Shale and plans to remain at this level for the remainder of the year.
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the first quarter of 2017 was 12,059 barrels of oil equivalent (Boe) per day (84% oil), an increase of 15 percent sequentially compared to the fourth quarter of 2016. During the first quarter, the Company drilled 7 net wells and completed and placed on production 10 net wells.
Cabot's operating efficiencies in the Eagle Ford Shale continue to improve, highlighted by another record-low quarter for drilling costs per foot, which were 13 percent lower in the first quarter of 2017 as compared to the full-year 2016 average.
Cabot is currently operating one rig and utilizing one completion crew in the Eagle Ford Shale and plans to remain at this level for the remainder of the year.
Financial Position and Liquidity
As of March 31, 2017, Cabot had total debt of $1.5 billion and cash on hand of $537.5 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 26.6 percent and 1.3x, respectively, compared to 28.5 percent and 1.8x as of December 31, 2016.
Effective April 11, 2017, Cabot's borrowing base was unanimously reaffirmed by its 20 lenders at $3.2 billion. Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to Cabot. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity. Cabot's next annual borrowing base redetermination is scheduled for April 2018.
Second Quarter and Full-Year 2017 Guidance Update
Cabot has provided second quarter 2017 net production guidance of 1,780 to 1,820 Mmcf per day for natural gas; 12,000 to 12,500 Bbls per day for crude oil and condensate; and 1,350 to 1,400 Bbls per day for NGLs.
Based on recent outperformance from its fourth generation Marcellus wells, coupled with an improving natural gas price outlook throughout Appalachia, the Company has increased its 2017 production growth guidance range from 5 - 10 percent to 8 - 12 percent. Additionally, the Company has increased its capital budget for the year to reflect an increase of up to $125 million for exploratory leasing and testing, resulting in full-year 2017 exploration and production (E&P) spending of up to $775 million (depending on the success of its exploratory activities). In addition, Cabot anticipates approximately $70 million of contributions to its equity pipeline investments resulting in total 2017 program spending of $845 million. Despite the increase in spending, the Company is currently forecasting over $250 million of positive free cash flow for the year based on recent Strip prices.
For further disclosure on Cabot's natural gas pricing exposure by index and cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast and Supplemental Earnings Materials
A conference call is scheduled for Friday, April 28, 2017, at 9:30 a.m. Eastern Time to discuss first quarter 2017 financial and operating results. A supplemental presentation is also available in the Investor Relations section of the Company's website at www.cabotog.com. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||
Three Months Ended | |||||||
2017 |
2016 | ||||||
PRODUCTION VOLUMES |
|||||||
Natural gas (Bcf) |
163.8 |
153.1 |
|||||
Crude oil and condensate (Mbbl) |
921.0 |
1,109.6 |
|||||
Natural gas liquids (NGLs) (Mbbl) |
123.5 |
92.1 |
|||||
Equivalent production (Bcfe) |
170.1 |
160.3 |
|||||
AVERAGE SALES PRICE |
|||||||
Natural gas, including hedges ($/Mcf) |
$ |
2.64 |
$ |
1.49 |
|||
Natural gas, excluding hedges ($/Mcf) |
$ |
2.65 |
$ |
1.49 |
|||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
46.73 |
$ |
27.65 |
|||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
46.68 |
$ |
27.65 |
|||
NGL ($/Bbl) |
$ |
20.71 |
$ |
7.22 |
|||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||
Direct operations |
$ |
0.14 |
$ |
0.16 |
|||
Transportation and gathering |
0.73 |
0.68 |
|||||
Taxes other than income |
0.05 |
0.04 |
|||||
Exploration |
0.04 |
0.04 |
|||||
Depreciation, depletion and amortization |
0.79 |
1.01 |
|||||
General and administrative (excluding stock-based compensation) |
0.09 |
0.11 |
|||||
Stock-based compensation |
0.05 |
0.07 |
|||||
Interest expense |
0.12 |
0.15 |
|||||
$ |
2.01 |
$ |
2.26 |
||||
WELLS DRILLED (1) |
|||||||
Gross |
21 |
10 |
|||||
Net |
21.0 |
10.0 |
|||||
WELLS COMPLETED (1) |
|||||||
Gross |
25 |
15 |
|||||
Net |
24.0 |
15.0 |
(1) Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | ||||||||
Three Months Ended | ||||||||
(In thousands, except per share amounts) |
2017 |
2016 | ||||||
OPERATING REVENUES |
||||||||
Natural gas |
$ |
433,442 |
$ |
227,578 |
||||
Crude oil and condensate |
42,990 |
30,676 |
||||||
Gain on derivative instruments |
33,384 |
18,994 |
||||||
Brokered natural gas |
4,695 |
3,180 |
||||||
Other |
3,332 |
1,513 |
||||||
517,843 |
281,941 |
|||||||
OPERATING EXPENSES |
||||||||
Direct operations |
24,641 |
26,035 |
||||||
Transportation and gathering |
123,474 |
109,652 |
||||||
Brokered natural gas |
4,046 |
2,566 |
||||||
Taxes other than income |
9,058 |
5,994 |
||||||
Exploration |
6,198 |
6,383 |
||||||
Depreciation, depletion and amortization |
135,100 |
161,887 |
||||||
General and administrative (excluding stock-based compensation) |
15,447 |
17,267 |
||||||
Stock-based compensation(1) |
8,253 |
10,606 |
||||||
326,217 |
340,390 |
|||||||
Earnings (loss) on equity method investments |
(1,283) |
2,009 |
||||||
Gain (loss) on sale of assets |
(223) |
1,354 |
||||||
INCOME (LOSS) FROM OPERATIONS |
190,120 |
(55,086) |
||||||
Interest expense |
20,771 |
24,375 |
||||||
Other expense |
424 |
503 |
||||||
Income (loss) before income taxes |
168,925 |
(79,964) |
||||||
Income tax expense (benefit) |
63,205 |
(28,770) |
||||||
NET INCOME (LOSS) |
$ |
105,720 |
$ |
(51,194) |
||||
Earnings (loss) per share - Basic |
$ |
0.23 |
$ |
(0.12) |
||||
Weighted-average common shares outstanding |
465,348 |
431,841 |
(1) Includes the impact of the Company's performance share awards, restricted stock, stock appreciation rights and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
March 31, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
748,313 |
$ |
715,881 |
|||
Properties and equipment, net (Successful efforts method) |
4,328,360 |
4,250,125 |
|||||
Other assets |
167,715 |
156,563 |
|||||
$ |
5,244,388 |
$ |
5,122,569 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
224,395 |
$ |
257,812 |
|||
Long-term debt, net |
1,520,870 |
1,520,530 |
|||||
Deferred income taxes |
590,575 |
579,447 |
|||||
Other liabilities |
201,369 |
197,113 |
|||||
Stockholders' equity |
2,707,179 |
2,567,667 |
|||||
$ |
5,244,388 |
$ |
5,122,569 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||
Three Months Ended | |||||||
(In thousands) |
2017 |
2016 | |||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||
Net income (loss) |
$ |
105,720 |
$ |
(51,194) |
|||
Deferred income tax expense (benefit) |
53,289 |
(28,973) |
|||||
(Gain) loss on sale of assets |
223 |
(1,354) |
|||||
Exploratory dry hole cost |
2,842 |
— |
|||||
Gain on derivative instruments |
(33,384) |
(18,994) |
|||||
Net cash paid in settlement of derivative instruments |
(1,524) |
— |
|||||
Income charges not requiring cash |
145,855 |
171,675 |
|||||
Changes in assets and liabilities |
(3,643) |
(4,048) |
|||||
Net cash provided by operating activities |
269,378 |
67,112 |
|||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||
Capital expenditures |
(208,384) |
(92,237) |
|||||
Proceeds from sale of assets |
374 |
49,828 |
|||||
Investment in equity method investments |
(7,742) |
(11,652) |
|||||
Net cash used in investing activities |
(215,752) |
(54,061) |
|||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||
Net borrowings (repayments) of debt |
— |
(413,000) |
|||||
Sale of common stock, net |
— |
995,278 |
|||||
Dividends paid |
(9,306) |
(8,282) |
|||||
Tax withholdings on stock award vestings |
(5,414) |
(5,022) |
|||||
Capitalized debt issuance costs |
— |
(3,223) |
|||||
Other |
37 |
— |
|||||
Net cash provided by (used in) financing activities |
(14,683) |
565,751 |
|||||
Net increase in cash and cash equivalents |
$ |
38,943 |
$ |
578,802 |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||
Three Months Ended | |||||||
(In thousands, except per share amounts) |
2017 |
2016 | |||||
As reported - net income (loss) |
$ |
105,720 |
$ |
(51,194) |
|||
Reversal of selected items: |
|||||||
(Gain) loss on sale of assets |
223 |
(1,354) |
|||||
(Gain) loss on derivative instruments(1) |
(34,908) |
(18,994) |
|||||
Drilling rig termination fees |
— |
3,188 |
|||||
Stock-based compensation expense |
8,253 |
10,606 |
|||||
Tax effect on selected items |
9,767 |
2,382 |
|||||
Net income (loss) excluding selected items |
$ |
89,055 |
$ |
(55,366) |
|||
As reported - earnings (loss) per share |
$ |
0.23 |
$ |
(0.12) |
|||
Per share impact of selected items |
(0.04) |
(0.01) |
|||||
Earnings (loss) per share excluding selected items |
$ |
0.19 |
$ |
(0.13) |
|||
Weighted-average common shares outstanding |
465,348 |
431,841 |
(1) This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||
Three Months Ended | |||||||
(In thousands) |
2017 |
2016 | |||||
Net income (loss) |
$ |
105,720 |
$ |
(51,194) |
|||
Plus (less): |
|||||||
Deferred income tax expense (benefit) |
53,289 |
(28,973) |
|||||
(Gain) loss on sale of assets |
223 |
(1,354) |
|||||
Exploratory dry hole cost |
2,842 |
— |
|||||
Gain on derivative instruments |
(33,384) |
(18,994) |
|||||
Net cash paid in settlement of derivative instruments |
(1,524) |
— |
|||||
Income charges not requiring cash |
145,855 |
171,675 |
|||||
Discretionary cash flow |
273,021 |
71,160 |
|||||
Changes in assets and liabilities |
(3,643) |
(4,048) |
|||||
Net cash provided by operating activities |
$ |
269,378 |
$ |
67,112 |
EBITDAX Calculation and Reconciliation | |||||||
Three Months Ended | |||||||
(In thousands) |
2017 |
2016 | |||||
Net income (loss) |
$ |
105,720 |
$ |
(51,194) |
|||
Plus (less): |
|||||||
Interest expense |
20,771 |
24,375 |
|||||
Other expense |
424 |
503 |
|||||
Income tax expense (benefit) |
63,205 |
(28,770) |
|||||
Depreciation, depletion and amortization |
135,100 |
161,887 |
|||||
Exploration |
6,198 |
6,383 |
|||||
(Gain) loss on sale of assets |
223 |
(1,354) |
|||||
Non-cash (gain) loss on derivative instruments |
(34,908) |
(18,994) |
|||||
(Earnings) loss on equity method investments |
1,283 |
(2,009) |
|||||
Stock-based compensation |
8,253 |
10,606 |
|||||
EBITDAX |
$ |
306,269 |
$ |
101,433 |
Net Debt Reconciliation | |||||||
(In thousands) |
March 31, |
December 31, | |||||
Total debt |
$ |
1,520,870 |
$ |
1,520,530 |
|||
Stockholders' equity |
2,707,179 |
2,567,667 |
|||||
Total capitalization |
$ |
4,228,049 |
$ |
4,088,197 |
|||
Total debt |
$ |
1,520,870 |
$ |
1,520,530 |
|||
Less: Cash and cash equivalents |
(537,485) |
(498,542) |
|||||
Net debt |
$ |
983,385 |
$ |
1,021,988 |
|||
Net debt |
$ |
983,385 |
$ |
1,021,988 |
|||
Stockholders' equity |
2,707,179 |
2,567,667 |
|||||
Total adjusted capitalization |
$ |
3,690,564 |
$ |
3,589,655 |
|||
Total debt to total capitalization ratio |
36.0 |
% |
37.2 |
% | |||
Less: Impact of cash and cash equivalents |
9.4 |
% |
8.7 |
% | |||
Net debt to adjusted capitalization ratio |
26.6 |
% |
28.5 |
% |
Capital Expenditures | ||||||||
Three Months Ended | ||||||||
(In thousands) |
2017 |
2016 | ||||||
Cash paid for capital expenditures |
$ |
208,384 |
$ |
92,237 |
||||
Change in accrued capital costs |
6,695 |
(549) |
||||||
Exploratory dry hole cost |
(2,842) |
— |
||||||
Capital expenditures |
$ |
212,237 |
$ |
91,688 |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 3, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its first quarter 2017 earnings conference call on Friday, April 28, 2017 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 24, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the fourth quarter and full-year ended December 31, 2016.
Highlights
"Our 2016 performance demonstrates Cabot's ability to deliver strong operational and financial results despite lower commodity prices for the majority of the year," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "The Company delivered production and reserves growth while spending within operating cash flow during a year in which we realized record-low natural gas prices, highlighting Cabot's world-class asset base and the consistent execution by our employees." Dinges added, "Based on our current outlook for 2017, we anticipate another year of production and reserves growth while generating positive free cash flow."
Full-Year 2016 Financial Results
Equivalent production was 627.1 billion cubic feet equivalent (Bcfe) in 2016, consisting of 600.4 Bcf of natural gas, 4,013.1 thousand barrels (Mbbls) of crude oil and condensate, and 441.2 Mbbls of natural gas liquids (NGLs).
Cash flow from operations was $392.4 million in 2016, compared to $740.7 million in 2015. Discretionary cash flow in 2016 was $460.7 million, compared to $699.1 million in 2015. Net loss in 2016 was $417.1 million, or $0.91 per share, compared to net loss of $113.9 million, or $0.28 per share, in 2015. Net loss for the year included the impact of a non-cash, after-tax impairment charge of $274.7 million associated with our oil and gas properties and related pipeline assets in West Virginia and Virginia. Excluding the effect of this impairment and other selected items (detailed in the table below), net loss was $97.4 million, or $0.21 per share, in 2016, compared to net income of $55.4 million, or $0.13 per share, in 2015. EBITDAX in 2016 was $554.4 million, compared to $815.2 million in 2015. Significant reductions in realized prices for both natural gas and oil were the primary drivers for the lower results during the year, partially offset by higher equivalent production and lower overall expenses. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $1.70 per Mcf in 2016, down 21 percent compared to 2015. Excluding the impact of derivatives, natural gas price realizations for 2016 implied a $0.76 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $37.30 per barrel (Bbl), down 18 percent compared to 2015. NGL price realizations were $11.74 per Bbl, down seven percent compared to 2015.
Operating expenses (including financing) decreased to $2.17 per Mcfe in 2016, an improvement of eight percent from $2.37 per Mcfe in 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.16 per Mcfe in 2016, an 11 percent improvement over 2015.
Cabot drilled 40 gross (38.0 net) wells and completed 76 gross (76.0 net) wells in 2016 and exited the year with 51 gross (45.2 net) drilled and uncompleted wells, of which 29 gross (26.2 net) were in the Marcellus Shale and 22 gross (19.0 net) were in the Eagle Ford Shale.
Fourth Quarter 2016 Financial Results
Equivalent production in the fourth quarter of 2016 was 164.2 Bcfe, consisting of 158.6 Bcf of natural gas, 822.7 Mbbls of crude oil and condensate, and 106.5 Mbbls of NGLs. Equivalent production increased nine percent sequentially compared to the third quarter of 2016 and was in line with the high-end of the Company's guidance range for the quarter.
Cash flow from operations in the fourth quarter of 2016 was $139.7 million, compared to $155.8 million in the fourth quarter of 2015. Discretionary cash flow in the fourth quarter of 2016 was $163.6 million, compared to $125.3 million in the fourth quarter of 2015. Net loss in the fourth quarter of 2016 was $292.8 million, or $0.63 per share, compared to a net loss of $111.1 million, or $0.27 per share, in the fourth quarter of 2015. Excluding the effect of the impairment and other selected items (detailed in the table below), net income was $5.1 million, or $0.01 per share, compared to net loss of $6.4 million, or $0.02 per share, for the fourth quarter of 2015. EBITDAX for the fourth quarter of 2016 was $187.4 million, compared to $164.2 million for the fourth quarter of 2015.
Natural gas price realizations, including the impact of derivatives, were $1.94 per Mcf both in the fourth quarter of 2016 and the fourth quarter of 2015. Excluding the impact of derivatives, natural gas price realizations for the quarter were $1.96 per Mcf, representing a $1.02 discount to NYMEX settlement prices. Oil price realizations, including the impact of derivatives, were $42.94 per Bbl, up 14 percent compared to the fourth quarter of 2015. NGL price realizations were $13.84 per Bbl, up 18 percent compared to the fourth quarter of 2015. "Fourth quarter natural gas and crude oil price realizations excluding the impact of derivatives posted a sequential increase of 9 percent and 11 percent, respectively, when compared to the third quarter, highlighting the improving commodity price backdrop," commented Dinges.
Operating expenses (including financing) decreased to $2.05 per Mcfe in the fourth quarter of 2016, an 11 percent improvement compared to $2.30 per Mcfe in the fourth quarter of 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.11 per Mcfe in the fourth quarter of 2016, a 12 percent improvement over the fourth quarter of 2015.
Cabot drilled 12 gross (10.0 net) wells and completed 25 gross (25.0 net) wells in the fourth quarter of 2016.
Year-End 2016 Financial Position and Liquidity
As of December 31, 2016, Cabot had total debt of $1.5 billion and cash on hand of $498.5 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 28.5 percent and 1.8x, respectively, compared to 50.1 percent and 2.5x as of December 31, 2015.
Total commitments under the Company's credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to the Company. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Year-End 2016 Proved Reserves
Cabot reported year-end proved reserves of 8.6 trillion cubic feet equivalent (Tcfe), an increase of five percent over year-end 2015. Specific highlights from the Company's year-end reserve report include:
"Despite our lowest level of capital spending since 2004, Cabot grew proved reserves and proved developed reserves by five percent and 16 percent, respectively, at record-low finding and development costs," explained Dinges. "We expect a return to double-digit reserve growth in 2017 as the Company increases its capital spending in anticipation of new takeaway capacity out of the Marcellus Shale."
The table below reconciles the components driving the 2016 reserve increase:
Proved Reserves Reconciliation (in Bcfe) | |
Balance at December 31, 2015 |
8,190 |
Revisions of prior estimates |
370 |
Extensions, discoveries and other additions |
684 |
Sales |
(41) |
Production |
(627) |
Balance at December 31, 2016 |
8,576 |
As of December 31, 2016, 97 percent of Cabot's year-end proved reserves were natural gas and 93 percent were located in the Marcellus Shale. Approximately 66 percent of the year-end proved reserves were classified as proved developed and 34 percent were classified as proved undeveloped (PUD), including six percent of drilled and uncompleted PUDs.
Total costs incurred during 2016 were $389.8 million, which included $359.5 million for development costs, $27.6 million for exploration costs, and $2.7 million for unproved property acquisition costs.
The SEC prices used for reporting Cabot's year-end 2016 proved reserves, which have been adjusted for basis and quality differentials, were $1.74 per Mcf for natural gas and $37.54 per Bbl for crude oil, representing a 4 percent and 20 percent year-over-year decrease, respectively. Assuming the SEC prices, the pre-tax present value of future net cash flows discounted at 10% ("pre-tax PV–10") of the year-end 2016 proved reserves was $2.6 billion. Assuming future strip benchmark pricing as of December 31, 2016 for the first five years and held flat thereafter, adjusted for basis and quality differentials, the pre-tax PV–10 value was $5.2 billion, representing a 100 percent increase over the corresponding SEC pre-tax PV–10.
Marcellus Shale Estimated Ultimate Recovery (EUR) Update
Based on Cabot's year-end reserve bookings for 21 producing Lower Marcellus wells that were completed with the Company's fourth generation completion design, Cabot has increased its guidance for Lower Marcellus EUR per 1,000 feet of lateral from 3.8 Bcf to 4.4 Bcf. "The EURs for our fourth generation wells further highlight the peer-leading productivity from our Marcellus assets in the core of the dry gas window in Northeast Pennsylvania," stated Dinges. "Based on our current well design and current commodity prices, we believe our project-level economics in the Marcellus are unrivaled across North American resource plays; however, we continue to test new initiatives to further enhance our economics."
2017 Derivative Position Update
For 2017 the Company has 51.7 Bcf of natural gas swaps at a weighted-average price of $3.23 per Mcf and 35.5 Bcf of natural gas collars at a weighted-average floor and ceiling price of $3.09 per Mcf and $3.43 per Mcf, respectively. Additionally, Cabot currently has 36 percent of its 2017 natural gas volumes under fixed-price physical contracts at a weighted-average price of $2.29 per Mcf.
The Company also has 1,825 Mbbls of crude oil collars at a weighted-average floor and ceiling price of $50.00 per Bbl and $56.39 per Bbl, respectively.
First Quarter and Full-Year 2017 Guidance Update
Cabot has provided first quarter 2017 net production guidance of 1,780 to 1,820 million cubic feet (Mmcf) per day for natural gas; 10,000 to 10,500 Bbls per day for crude oil and condensate; and 1,200 to 1,250 Bbls per day for NGLs.
The Company has reiterated its 2017 production growth guidance range of 5 to 10 percent and initiated crude oil production growth guidance of 15 percent, which represents a substantial increase from the zero percent oil growth contained in the preliminary 2017 budget issued in October 2016. Based on the expectation for higher operating cash flow due to an improvement in the commodity price outlook, the Company is increasing its exploration and production (E&P) capital budget from $575 million to $650 million. This incremental capital will fund additional drilling and completion activity, primarily in the Eagle Ford. "Cabot has seen a significant improvement in project-level returns in our Eagle Ford asset due to increased productivity from enhanced completions, continued cost reductions, and higher crude oil prices," said Dinges. "Accordingly, we plan to allocate additional capital to this asset to grow exit-to-exit crude oil volumes by 50 percent in 2017." Dinges added, "Even with this modest increase in capital for 2017, we are forecasting approximately $250 million of positive free cash flow for the year based on recent strip prices."
Drilling, completion and facility capital will account for approximately 94 percent of the E&P budget, with approximately 67 percent allocated to the Marcellus Shale and 33 percent allocated to the Eagle Ford Shale. The Company expects to drill an additional 20 net wells (15 in the Eagle Ford and 5 in the Marcellus) for total of 90 net wells drilled in 2017. The Company plans to complete an additional 15 net wells (14 in the Eagle Ford and 1 in the Marcellus) for a total of 90 net wells completed in 2017. In addition, Cabot anticipates approximately $70 million of contributions to its equity pipeline investments resulting in total 2017 program spending of $720 million. The capital associated with the equity pipeline investments assumes a more favorable outlook on the construction timing for Atlantic Sunrise and assumes minimal capital for Constitution Pipeline in 2017; however, the amount of pipeline investments will ultimately be dependent on the regulatory approval processes and the corresponding impact on the timing of construction activities.
For further disclosure on Cabot's natural gas pricing exposure by index and updated cost guidance, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call Webcast and Supplemental Earnings Materials
A conference call is scheduled for Friday, February 24, 2017, at 9:30 a.m. Eastern Time to discuss fourth quarter and full-year 2016 financial and operating results. A supplemental presentation is also available in the Investor Relations section of the Company's website at www.cabotog.com. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
158.6 |
142.8 |
600.4 |
566.0 |
|||||||||||
Crude oil and condensate (Mbbl) |
822.7 |
1,203.2 |
4,013.1 |
5,428.7 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
106.5 |
174.7 |
441.2 |
667.7 |
|||||||||||
Equivalent production (Bcfe) |
164.2 |
151.0 |
627.1 |
602.5 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
1.94 |
$ |
1.94 |
$ |
1.70 |
$ |
2.15 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
1.96 |
$ |
1.52 |
$ |
1.70 |
$ |
1.81 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
42.94 |
$ |
37.74 |
$ |
37.30 |
$ |
45.72 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
44.36 |
$ |
37.74 |
$ |
37.65 |
$ |
45.72 |
|||||||
NGL ($/Bbl) |
$ |
13.84 |
$ |
11.69 |
$ |
11.74 |
$ |
12.56 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.14 |
$ |
0.22 |
$ |
0.16 |
$ |
0.23 |
|||||||
Transportation and gathering |
0.69 |
0.70 |
0.70 |
0.71 |
|||||||||||
Taxes other than income |
0.03 |
0.06 |
0.05 |
0.07 |
|||||||||||
Exploration |
0.09 |
0.06 |
0.04 |
0.05 |
|||||||||||
Depreciation, depletion and amortization |
0.86 |
0.99 |
0.94 |
1.03 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.10 |
0.10 |
0.10 |
0.10 |
|||||||||||
Stock-based compensation |
0.02 |
0.01 |
0.04 |
0.02 |
|||||||||||
Interest expense |
0.12 |
0.16 |
0.14 |
0.16 |
|||||||||||
$ |
2.05 |
$ |
2.30 |
$ |
2.17 |
$ |
2.37 |
||||||||
WELLS DRILLED(1) |
|||||||||||||||
Gross |
12 |
26 |
40 |
138 |
|||||||||||
Net |
10.0 |
25.2 |
38.0 |
130.5 |
|||||||||||
WELLS COMPLETED(1) |
|||||||||||||||
Gross |
25 |
17 |
76 |
107 |
|||||||||||
Net |
25.0 |
13.3 |
76.0 |
98.9 |
|||||||||||
(1) |
Wells drilled represents wells drilled to total depth during the period. Wells completed includes wells completed during the period, regardless of when they were drilled. |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) |
2016 |
2015 |
2016 |
2015 | |||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
311,580 |
$ |
217,084 |
$ |
1,022,590 |
$ |
1,025,044 |
|||||||
Crude oil and condensate |
36,496 |
45,407 |
151,106 |
248,211 |
|||||||||||
Gain (loss) on derivative instruments |
(37,664) |
12,018 |
(38,950) |
56,686 |
|||||||||||
Brokered natural gas |
4,152 |
3,733 |
13,569 |
16,383 |
|||||||||||
Other |
1,927 |
2,550 |
7,362 |
10,826 |
|||||||||||
316,491 |
280,792 |
1,155,677 |
1,357,150 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
23,557 |
33,867 |
100,696 |
140,814 |
|||||||||||
Transportation and gathering |
113,659 |
105,936 |
436,542 |
427,588 |
|||||||||||
Brokered natural gas |
3,259 |
2,949 |
10,785 |
12,592 |
|||||||||||
Taxes other than income |
5,486 |
8,511 |
29,223 |
42,809 |
|||||||||||
Exploration |
14,553 |
8,500 |
27,662 |
27,460 |
|||||||||||
Depreciation, depletion and amortization |
141,218 |
149,876 |
590,128 |
622,211 |
|||||||||||
Impairment of oil and gas properties and other assets(1) |
435,619 |
114,875 |
435,619 |
114,875 |
|||||||||||
General and administrative (excluding stock-based compensation) |
15,891 |
13,777 |
61,274 |
55,764 |
|||||||||||
Stock-based compensation(2) |
2,952 |
2,058 |
25,968 |
13,680 |
|||||||||||
756,194 |
440,349 |
1,717,897 |
1,457,793 |
||||||||||||
Earnings (loss) on equity method investments |
(2,685) |
1,834 |
(2,477) |
6,415 |
|||||||||||
Gain (loss) on sale of assets |
(1,089) |
52 |
(1,857) |
3,866 |
|||||||||||
LOSS FROM OPERATIONS |
(443,477) |
(157,671) |
(566,554) |
(90,362) |
|||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Interest expense |
20,515 |
24,666 |
88,336 |
96,911 |
|||||||||||
Loss before income taxes |
(463,992) |
(182,337) |
(659,599) |
(187,273) |
|||||||||||
Income tax benefit |
(171,232) |
(71,213) |
(242,475) |
(73,382) |
|||||||||||
NET LOSS |
$ |
(292,760) |
$ |
(111,124) |
$ |
(417,124) |
$ |
(113,891) |
|||||||
Loss per share - Basic |
$ |
(0.63) |
$ |
(0.27) |
$ |
(0.91) |
$ |
(0.28) |
|||||||
Weighted-average common shares outstanding |
465,150 |
413,875 |
456,847 |
413,696 |
|||||||||||
(1) |
Includes the impairment of oil and gas properties and the related pipeline assets in West Virginia and Virginia in the fourth quarter of 2016. Also includes the impairment of oil and gas properties in the fourth quarter of 2015 in south Texas, east Texas and Louisiana. | |
(2) |
Includes the impact of the Company's performance share awards, restricted stock, stock appreciation rights and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) |
December 31, |
December 31, | |||||
ASSETS |
|||||||
Current assets |
$ |
715,881 |
$ |
144,786 |
|||
Properties and equipment, net (Successful efforts method) |
4,250,125 |
4,976,879 |
|||||
Other assets |
156,563 |
131,373 |
|||||
$ |
5,122,569 |
$ |
5,253,038 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
257,812 |
$ |
235,552 |
|||
Long-term debt, net (excluding current maturities) |
1,520,530 |
1,996,139 |
|||||
Deferred income taxes |
579,447 |
807,236 |
|||||
Other liabilities |
197,113 |
204,923 |
|||||
Stockholders' equity |
2,567,667 |
2,009,188 |
|||||
$ |
5,122,569 |
$ |
5,253,038 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands) |
2016 |
2015 |
2016 |
2015 | |||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net loss |
$ |
(292,760) |
$ |
(111,124) |
$ |
(417,124) |
$ |
(113,891) |
|||||||
Deferred income tax benefit |
(171,294) |
(81,194) |
(230,707) |
(72,968) |
|||||||||||
Impairment of oil and gas properties and other assets |
435,619 |
114,875 |
435,619 |
114,875 |
|||||||||||
(Gain) loss on sale of assets |
1,089 |
(52) |
1,857 |
(3,866) |
|||||||||||
Exploratory dry hole cost |
10,102 |
3,268 |
10,120 |
3,452 |
|||||||||||
(Gain) loss on derivative instruments |
37,664 |
(12,018) |
38,950 |
(56,686) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
(4,886) |
60,462 |
(1,682) |
194,289 |
|||||||||||
Income charges not requiring cash |
148,029 |
151,124 |
623,670 |
633,895 |
|||||||||||
Changes in assets and liabilities |
(23,835) |
30,442 |
(68,326) |
41,637 |
|||||||||||
Net cash provided by operating activities |
139,728 |
155,783 |
392,377 |
740,737 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(130,120) |
(135,763) |
(375,153) |
(955,602) |
|||||||||||
Acquisitions |
— |
— |
— |
(16,312) |
|||||||||||
Proceeds from sale of assets |
1,351 |
273 |
50,419 |
7,653 |
|||||||||||
Investment in equity method investments |
(4,308) |
(8,275) |
(28,484) |
(29,073) |
|||||||||||
Net cash used in investing activities |
(133,077) |
(143,765) |
(353,218) |
(993,334) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net borrowings (repayments) of debt |
— |
(12,000) |
(497,000) |
273,000 |
|||||||||||
Sale of common stock, net |
— |
— |
995,279 |
— |
|||||||||||
Dividends paid |
(9,302) |
(8,278) |
(36,187) |
(33,090) |
|||||||||||
Capitalized debt issuance costs |
— |
— |
(3,223) |
(7,838) |
|||||||||||
Other |
— |
1 |
— |
85 |
|||||||||||
Net cash provided by (used in) financing activities |
(9,302) |
(20,277) |
458,869 |
232,157 |
|||||||||||
Net increase (decrease) in cash and cash equivalents |
$ |
(2,651) |
$ |
(8,259) |
$ |
498,028 |
$ |
(20,440) |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands, except per share amounts) |
2016 |
2015 |
2016 |
2015 | |||||||||||
As reported - net loss |
$ |
(292,760) |
$ |
(111,124) |
$ |
(417,124) |
$ |
(113,891) |
|||||||
Reversal of selected items: |
|||||||||||||||
Impairment of oil and gas properties and other assets |
435,619 |
114,875 |
435,619 |
114,875 |
|||||||||||
(Gain) loss on sale of assets |
1,089 |
(52) |
1,857 |
(3,866) |
|||||||||||
(Gain) loss on derivative instruments(1) |
32,778 |
48,444 |
37,268 |
137,603 |
|||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Drilling rig termination fees |
— |
— |
1,655 |
5,084 |
|||||||||||
Stock-based compensation expense |
2,952 |
2,058 |
25,968 |
13,680 |
|||||||||||
Tax effect on selected items |
(174,567) |
(60,646) |
(187,366) |
(98,081) |
|||||||||||
Net income (loss) excluding selected items |
$ |
5,111 |
$ |
(6,445) |
$ |
(97,414) |
$ |
55,404 |
|||||||
As reported - loss per share |
$ |
(0.63) |
$ |
(0.27) |
$ |
(0.91) |
$ |
(0.28) |
|||||||
Per share impact of selected items |
0.64 |
0.25 |
0.70 |
0.41 |
|||||||||||
Earnings (loss) per share excluding selected items |
$ |
0.01 |
$ |
(0.02) |
$ |
(0.21) |
$ |
0.13 |
|||||||
Weighted-average common shares outstanding |
465,150 |
413,875 |
456,847 |
413,696 |
|||||||||||
(1) |
This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands) |
2016 |
2015 |
2016 |
2015 | |||||||||||
Net loss |
$ |
(292,760) |
$ |
(111,124) |
$ |
(417,124) |
$ |
(113,891) |
|||||||
Plus (less): |
|||||||||||||||
Deferred income tax benefit |
(171,294) |
(81,194) |
(230,707) |
(72,968) |
|||||||||||
Impairment of oil and gas properties and other assets |
435,619 |
114,875 |
435,619 |
114,875 |
|||||||||||
(Gain) loss on sale of assets |
1,089 |
(52) |
1,857 |
(3,866) |
|||||||||||
Exploratory dry hole cost |
10,102 |
3,268 |
10,120 |
3,452 |
|||||||||||
(Gain) loss on derivative instruments |
37,664 |
(12,018) |
38,950 |
(56,686) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
(4,886) |
60,462 |
(1,682) |
194,289 |
|||||||||||
Income charges not requiring cash |
148,029 |
151,124 |
623,670 |
633,895 |
|||||||||||
Discretionary cash flow |
163,563 |
125,341 |
460,703 |
699,100 |
|||||||||||
Changes in assets and liabilities |
(23,835) |
30,442 |
(68,326) |
41,637 |
|||||||||||
Net cash provided by operations |
$ |
139,728 |
$ |
155,783 |
$ |
392,377 |
$ |
740,737 |
EBITDAX Calculation and Reconciliation | |||||||||||||||
Quarter Ended December 31, |
Twelve Months Ended December 31, | ||||||||||||||
(In thousands) |
2016 |
2015 |
2016 |
2015 | |||||||||||
Net loss |
$ |
(292,760) |
$ |
(111,124) |
$ |
(417,124) |
$ |
(113,891) |
|||||||
Plus (less): |
|||||||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Interest expense |
20,515 |
24,666 |
88,336 |
96,911 |
|||||||||||
Income tax benefit |
(171,232) |
(71,213) |
(242,475) |
(73,382) |
|||||||||||
Depreciation, depletion and amortization |
141,218 |
149,876 |
590,128 |
622,211 |
|||||||||||
Impairment of oil and gas properties and other assets |
435,619 |
114,875 |
435,619 |
114,875 |
|||||||||||
Exploration |
14,553 |
8,500 |
27,662 |
27,460 |
|||||||||||
(Gain) loss on sale of assets |
1,089 |
(52) |
1,857 |
(3,866) |
|||||||||||
Non-cash (gain) loss on derivative instruments |
32,778 |
48,444 |
37,268 |
137,603 |
|||||||||||
(Earnings) loss on equity method investments |
2,685 |
(1,834) |
2,477 |
(6,415) |
|||||||||||
Stock-based compensation |
2,952 |
2,058 |
25,968 |
13,680 |
|||||||||||
EBITDAX |
$ |
187,417 |
$ |
164,196 |
$ |
554,425 |
$ |
815,186 |
Net Debt Reconciliation | |||||||
(In thousands) |
December 31, |
December 31, | |||||
Current portion of long-term debt |
$ |
— |
$ |
20,000 |
|||
Long-term debt, net |
1,520,530 |
1,996,139 |
|||||
Total debt |
$ |
1,520,530 |
$ |
2,016,139 |
|||
Stockholders' equity |
2,567,667 |
2,009,188 |
|||||
Total capitalization |
$ |
4,088,197 |
$ |
4,025,327 |
|||
Total debt |
$ |
1,520,530 |
$ |
2,016,139 |
|||
Less: Cash and cash equivalents |
(498,542) |
(514) |
|||||
Net debt |
$ |
1,021,988 |
$ |
2,015,625 |
|||
Net debt |
$ |
1,021,988 |
$ |
2,015,625 |
|||
Stockholders' equity |
2,567,667 |
2,009,188 |
|||||
Total adjusted capitalization |
$ |
3,589,655 |
$ |
4,024,813 |
|||
Total debt to total capitalization ratio |
37.2 |
% |
50.1 |
% | |||
Less: Impact of cash and cash equivalents |
8.7 |
% |
— |
% | |||
Net debt to adjusted capitalization ratio |
28.5 |
% |
50.1 |
% |
Pre-tax Present Value of Future Net Cash Flows Calculation and Reconciliation | |||||||
(In thousands) |
December 31, |
December 31, | |||||
Standardized Measure of Discounted Future Net Cash Flows |
$ |
2,234,767 |
$ |
2,858,832 |
|||
Plus: Future Income Tax Expenses, discounted at 10% annual rate |
380,276 |
— |
|||||
Pre-tax Present Value of Future Net Cash Flows, discounted at 10% annual rate |
$ |
2,615,043 |
$ |
2,858,832 |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 25, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its fourth quarter and full year 2016 earnings conference call on Friday, February 24, 2017 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Jan. 6, 2017 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of two cents ($0.02) per share on the Company's common stock. The dividend will be paid February 9, 2017 to all shareholders of record as of the close of business January 26, 2017.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Dec. 30, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today announced that the Federal Energy Regulatory Commission ("FERC") issued its final Environmental Impact Statement ("EIS") for Williams Partners' (NYSE: WPZ) Atlantic Sunrise project. The issuance of the final EIS is a key step toward the FERC's final decision on the project, which is expected in early 2017. Following the receipt of all necessary regulatory approvals, Williams Partners anticipates beginning construction in mid-2017, allowing for a full in-service of the project in mid-2018.
In addition to previously announced gas sale and purchase agreements related to Cabot's 850,000 MMBtu per day of transportation capacity on the Atlantic Sunrise project, Cabot also reported the execution of a new definitive gas sale and purchase agreement with an undisclosed company. Under the terms of this new agreement, the Company has agreed to sell an additional 150,000 MMBtu per day of natural gas for a term of three years commencing on the full in-service of the Atlantic Sunrise project.
"Today's final EIS issuance represents a major milestone toward the final approval of the Atlantic Sunrise project," commented Dan O. Dinges, Chairman, President and Chief Executive Officer. "We are also excited to increase our committed sales on the Atlantic Sunrise project utilizing capacity subscribed to by Cabot or by third parties to approximately 1 billion cubic feet (Bcf) per day through the addition of this new sales agreement that is linked to the Gulf Coast market."
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 28, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the third quarter of 2016. Highlights for the quarter include:
"The volatility in commodity prices continues to challenge our industry and has driven us to be more efficient," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "We have been successful at creating a free cash flow positive investment program that still generates growth, while simultaneously driving down our cost structure and our resulting breakeven levels." Dinges added, "While our impatience with the regulatory pipeline approval process is very real, it has not impacted our focus on prudently managing this business for the long-term as evidenced by our results this quarter."
Third Quarter 2016 Financial Results
Equivalent production in the third quarter of 2016 was 150.8 billion cubic feet equivalent (Bcfe), consisting of 144.4 billion cubic feet (Bcf) of natural gas, 941.4 thousand barrels (Mbbls) of crude oil and condensate, and 129.6 Mbbls of natural gas liquids (NGLs). The Company estimates that downstream maintenance projects and unscheduled upstream gathering downtime negatively impacted natural gas production for the quarter by approximately 3.2 Bcf, or 35 million cubic feet (Mmcf) per day.
Cash flow from operating activities in the third quarter of 2016 was $105.4 million, compared to $146.4 million in the third quarter of 2015. Discretionary cash flow in the third quarter of 2016 was $128.4 million, compared to $150.4 million in the third quarter of 2015. Net loss in the third quarter of 2016 was $10.3 million, or $0.02 per share, compared to net loss of $15.5 million, or $0.04 per share, in the third quarter of 2015. Excluding the effect of selected items (detailed in the table below), net loss in the third quarter of 2016 was $16.7 million, or $0.04 per share, compared to net loss of $2.2 million, or $0.01 per share, in the third quarter of 2015. EBITDAX in the third quarter of 2016 was $138.8 million, compared to $167.6 million in the third quarter of 2015. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $1.75 per thousand cubic feet (Mcf) in the third quarter of 2016, down 13 percent compared to the third quarter of 2015. Excluding the impact of derivatives, natural gas price realizations for the quarter implied a $1.01 discount to NYMEX settlement prices compared to a $1.09 discount to NYMEX settlement prices in the third quarter of 2015. Oil price realizations, including the impact of derivatives, were $40.13 per barrel (Bbl), down eight percent compared to the third quarter of 2015. NGL price realizations were $12.64 per Bbl, up 25 percent compared to the third quarter of 2015.
Operating expenses (including financing) decreased to $2.14 per thousand cubic feet equivalent (Mcfe) in the third quarter of 2016, a nine percent improvement compared to $2.35 per Mcfe in the third quarter of 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.17 per Mcfe in the third quarter of 2016, a 13 percent improvement compared to $1.34 per Mcfe in the third quarter of 2015.
Cabot drilled 11 net wells and completed 23 net wells during the third quarter of 2016, incurring a total of $99.5 million in capital expenditures associated with activity during this period.
Year-To-Date 2016 Financial Results
Equivalent production for the nine-month period ended September 30, 2016 was 463.0 Bcfe, consisting of 441.8 Bcf of natural gas, 3,190.4 Mbbls of crude oil and condensate, and 334.6 Mbbls of NGLs.
For the nine-month period ended September 30, 2016, cash flow from operating activities was $252.6 million, compared to $585.0 million for the nine-month period ended September 30, 2015. Discretionary cash flow was $297.1 million for the nine-month period ended September 30, 2016, compared to $573.8 million for the nine-month period ended September 30, 2015. For the nine-month period ended September 30, 2016, net loss was $124.4 million, or $0.27 per share, compared to net loss of $2.8 million, or $0.01 per share, for the nine-month period ended September 30, 2015. Excluding the effect of selected items, net loss was $102.3 million, or $0.23 per share, compared to net income of $62.5 million, or $0.15 per share, for the nine-month period ended September 30, 2015. EBITDAX for the nine-month period ended September 30, 2016 was $367.0 million, compared to $651.0 million for the nine-month period ended September 30, 2015.
Natural gas price realizations, including the impact of derivatives, were $1.62 per Mcf for the nine-month period ended September 30, 2016, down 27 percent compared to the nine-month period ended September 30, 2015. Oil price realizations, including the impact of derivatives, were $35.85 per Bbl, down 25 percent compared to the nine-month period ended September 30, 2015. NGL price realizations were $11.08 per Bbl, down 14 percent compared to the nine-month period ended September 30, 2015.
Operating expenses (including financing) decreased to $2.21 per Mcfe for the nine-month period ended September 30, 2016, an eight percent improvement compared to $2.40 per Mcfe for the nine-month period ended September 30, 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.18 per Mcfe for the nine-month period ended September 30, 2016, a 10 percent improvement compared to $1.31 per Mcfe in the nine-month period ended September 30, 2015.
Cabot drilled 28 net wells and completed 55 net wells during the nine-month period ended September 30, 2016, incurring a total of $262.1 million in capital expenditures associated with activity during this period.
Financial Position and Liquidity
As of September 30, 2016, Cabot had total debt of $1.5 billion and cash on hand of $501.2 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 26.2 percent and 1.9x, respectively, compared to 50.1 percent and 2.5x as of December 31, 2015.
Total commitments under the Company's revolving credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to the Company. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Fourth Quarter and Full-Year 2016 Guidance
Cabot has provided fourth quarter net production guidance of 1,650 to 1,725 Mmcf per day for natural gas; 8,500 to 9,000 Bbls per day for crude oil and condensate; and 1,000 to 1,050 Bbls per day for NGLs.
Based on the fourth quarter production guidance, the Company has adjusted its full-year 2016 equivalent production growth guidance range to 3 to 4 percent. Additionally, Cabot is increasing its 2016 capital budget guidance by $35 million to $380 million. This increase reflects the drilling and completion of an additional 8 net wells during the fourth quarter and the implementation of Cabot's fourth-generation completion design across its entire Marcellus Shale program beginning in the fourth quarter. "We have seen tremendous success from our fourth-generation completion pilot tests as these wells have significantly outperformed the third-generation wells drilled on the same pad site," highlighted Dinges. "As a result, we plan to utilize this new completion design moving forward given the material uplift in economics we have realized."
Full-Year 2017 Guidance and Preliminary 2018 Outlook
The Company has initiated its 2017 production growth guidance range at 5 to 10 percent. This production growth range is based on an exploration and production (E&P) capital budget of $575 million. In addition, Cabot anticipates approximately $50 million of contributions to its equity method investments in the Atlantic Sunrise and Constitution pipelines, resulting in total 2017 program spending of $625 million. Drilling, completion and facility capital will account for approximately 93 percent of the E&P budget, with approximately 79 percent allocated to the Marcellus Shale and 21 percent allocated to the Eagle Ford Shale. The Company expects to drill approximately 70 net wells (including 55 net wells in the Marcellus Shale and 15 net wells in the Eagle Ford Shale) and complete approximately 75 net wells (including 50 net wells in the Marcellus Shale and 25 net wells in the Eagle Ford Shale). The average lateral length for the 2017 drilling program in the Marcellus Shale is expected to be 8,000 feet and will utilize the fourth-generation completion design, resulting in 53 completed stages per well. The average lateral length for the 2017 drilling program in the Eagle Ford Shale is expected to be 9,000 feet with 36 completed stages per well. Approximately $225 million of the drilling, completion and facility capital is the maintenance capital required to hold Cabot's anticipated 2016 exit production rate flat throughout 2017, which would result in full-year production growth near the low-end of the production growth guidance range, while allowing the Company to meet all obligatory leasehold commitments. The remainder of the drilling, completion and facility capital will be used to fund incremental growth in 2017 and position the Company for production growth of 15 to 25 percent in 2018. This preliminary outlook for 2018 is predicated on Cabot's current expected in-service dates for its new takeaway capacity, which are referenced in the supplemental materials posted to the Company's website this morning, including a mid-2018 in-service date for Atlantic Sunrise.
Conference Call Webcast and Supplemental Earnings Materials
A conference call is scheduled for Friday, October 28, 2016, at 9:30 a.m. Eastern Time to discuss third quarter 2016 financial and operating results as well as fourth quarter 2016 and full-year 2017 guidance. A supplemental presentation is also available in the Investor Relations section of the Company's website at www.cabotog.com. To access the live audio webcast, please visit the Investor Relations section of the Company's website. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
This press release includes forward‐looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The statements regarding future financial and operating performance and results, strategic pursuits and goals, market prices, future hedging and risk management activities, and other statements that are not historical facts contained in this report are forward-looking statements. The words "expect", "project", "estimate", "believe", "anticipate", "intend", "budget", "plan", "forecast", "predict", "may", "should", "could", "will" and similar expressions are also intended to identify forward-looking statements. Such statements involve risks and uncertainties, including, but not limited to, market factors, market prices (including geographic basis differentials) of natural gas and crude oil, results of future drilling and marketing activity, future production and costs, legislative and regulatory initiatives, electronic, cyber or physical security breaches and other factors detailed herein and in our other Securities and Exchange Commission (SEC) filings. See "Risk Factors" in Item 1A of the Form 10-K and subsequent public filings for additional information about these risks and uncertainties. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual outcomes may vary materially from those indicated. Any forward-looking statement speaks only as of the date on which such statement is made, and the Company does not undertake any obligation to correct or update any forward-looking statement, whether as the result of new information, future events or otherwise, except as required by applicable law.
OPERATING DATA | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
144.4 |
133.0 |
441.8 |
423.2 |
|||||||||||
Crude oil and condensate (Mbbl) |
941.4 |
1,350.0 |
3,190.4 |
4,225.5 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
129.6 |
162.9 |
334.6 |
493.0 |
|||||||||||
Equivalent production (Bcfe) |
150.8 |
142.1 |
463.0 |
451.5 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
1.75 |
$ |
2.02 |
$ |
1.62 |
$ |
2.23 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
1.80 |
$ |
1.68 |
$ |
1.61 |
$ |
1.91 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
40.13 |
$ |
43.71 |
$ |
35.85 |
$ |
48.00 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
40.13 |
$ |
43.71 |
$ |
35.92 |
$ |
48.00 |
|||||||
NGL ($/Bbl) |
$ |
12.64 |
$ |
10.11 |
$ |
11.08 |
$ |
12.87 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.16 |
$ |
0.25 |
$ |
0.17 |
$ |
0.24 |
|||||||
Transportation and gathering |
0.70 |
0.72 |
0.70 |
0.71 |
|||||||||||
Taxes other than income |
0.06 |
0.08 |
0.05 |
0.08 |
|||||||||||
Exploration |
0.02 |
0.03 |
0.03 |
0.04 |
|||||||||||
Depreciation, depletion and amortization |
0.92 |
1.02 |
0.97 |
1.05 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.10 |
0.10 |
0.10 |
0.09 |
|||||||||||
Stock-based compensation |
0.03 |
(0.02) |
0.05 |
0.03 |
|||||||||||
Interest expense |
0.14 |
0.17 |
0.15 |
0.16 |
|||||||||||
$ |
2.14 |
$ |
2.35 |
$ |
2.21 |
$ |
2.40 |
||||||||
WELLS DRILLED |
|||||||||||||||
Gross |
11 |
27 |
28 |
114 |
|||||||||||
Net |
11 |
27 |
28 |
105 |
|||||||||||
Gross success rate |
100 |
% |
100 |
% |
100 |
% |
100 |
% | |||||||
WELLS COMPLETED |
|||||||||||||||
Gross |
23 |
21 |
55 |
96 |
|||||||||||
Net |
23 |
18 |
55 |
90 |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
260,200 |
$ |
222,963 |
$ |
711,010 |
$ |
807,960 |
|||||||
Crude oil and condensate |
37,777 |
59,014 |
114,610 |
202,804 |
|||||||||||
Gain (loss) on derivative instruments |
6,904 |
17,364 |
(1,286) |
44,668 |
|||||||||||
Brokered natural gas |
3,641 |
4,010 |
9,417 |
12,650 |
|||||||||||
Other |
1,907 |
1,945 |
5,435 |
8,277 |
|||||||||||
310,429 |
305,296 |
839,186 |
1,076,359 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
24,626 |
34,818 |
77,139 |
106,947 |
|||||||||||
Transportation and gathering |
105,671 |
102,121 |
322,883 |
321,652 |
|||||||||||
Brokered natural gas |
2,939 |
3,020 |
7,526 |
9,643 |
|||||||||||
Taxes other than income |
8,771 |
11,407 |
23,737 |
34,298 |
|||||||||||
Exploration |
2,988 |
4,930 |
13,109 |
18,960 |
|||||||||||
Depreciation, depletion and amortization |
139,490 |
144,326 |
448,910 |
472,335 |
|||||||||||
General and administrative (excluding stock-based compensation) |
14,667 |
14,015 |
45,383 |
41,989 |
|||||||||||
Stock-based compensation(1) |
5,109 |
(2,913) |
23,016 |
11,622 |
|||||||||||
304,261 |
311,724 |
961,703 |
1,017,446 |
||||||||||||
Earnings (loss) on equity method investments |
(1,727) |
1,648 |
208 |
4,581 |
|||||||||||
Gain (loss) on sale of assets |
(1,245) |
3,756 |
(768) |
3,814 |
|||||||||||
INCOME (LOSS) FROM OPERATIONS |
3,196 |
(1,024) |
(123,077) |
67,308 |
|||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Interest expense |
21,483 |
24,510 |
67,821 |
72,244 |
|||||||||||
Income (loss) before income taxes |
(18,287) |
(25,534) |
(195,607) |
(4,936) |
|||||||||||
Income tax expense (benefit) |
(8,027) |
(10,020) |
(71,243) |
(2,169) |
|||||||||||
NET INCOME (LOSS) |
$ |
(10,260) |
$ |
(15,514) |
$ |
(124,364) |
$ |
(2,767) |
|||||||
Earnings (loss) per share - Basic |
$ |
(0.02) |
$ |
(0.04) |
$ |
(0.27) |
$ |
(0.01) |
|||||||
Weighted-average common shares outstanding |
465,149 |
413,846 |
454,060 |
413,636 |
|||||||||||
(1) Includes the impact of the Company's performance share awards, restricted stock, stock appreciation rights and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | |||||||
September 30, |
December 31, | ||||||
ASSETS |
|||||||
Current assets |
$ |
655,645 |
$ |
144,786 |
|||
Properties and equipment, net (Successful efforts method) |
4,722,598 |
4,976,879 |
|||||
Other assets |
153,678 |
131,373 |
|||||
$ |
5,531,921 |
$ |
5,253,038 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
196,763 |
$ |
235,552 |
|||
Long-term debt, net (excluding current maturities) |
1,520,190 |
1,996,139 |
|||||
Deferred income taxes |
749,976 |
807,236 |
|||||
Other liabilities |
201,742 |
204,923 |
|||||
Stockholders' equity |
2,863,250 |
2,009,188 |
|||||
$ |
5,531,921 |
$ |
5,253,038 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income (loss) |
$ |
(10,260) |
$ |
(15,514) |
$ |
(124,364) |
$ |
(2,767) |
|||||||
Deferred income tax expense (benefit) |
4,880 |
1,066 |
(59,413) |
8,226 |
|||||||||||
(Gain) loss on sale of assets |
1,245 |
(3,756) |
768 |
(3,814) |
|||||||||||
Exploratory dry hole cost |
— |
6 |
18 |
184 |
|||||||||||
(Gain) loss on derivative instruments |
(6,904) |
(17,364) |
1,286 |
(44,668) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
(8,101) |
45,097 |
3,204 |
133,827 |
|||||||||||
Income charges not requiring cash |
147,502 |
140,823 |
475,641 |
482,771 |
|||||||||||
Changes in assets and liabilities |
(22,957) |
(3,996) |
(44,491) |
11,195 |
|||||||||||
Net cash provided by operating activities |
105,405 |
146,362 |
252,649 |
584,954 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(85,634) |
(174,747) |
(245,033) |
(819,839) |
|||||||||||
Acquisitions |
— |
(12) |
— |
(16,312) |
|||||||||||
Proceeds from sale of assets |
(760) |
4,378 |
49,068 |
7,380 |
|||||||||||
Investment in equity method investments |
(6,005) |
(10,684) |
(24,176) |
(20,798) |
|||||||||||
Net cash used in investing activities |
(92,399) |
(181,065) |
(220,141) |
(849,569) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net borrowings (repayments) of debt |
(20,000) |
42,000 |
(497,000) |
285,000 |
|||||||||||
Sale of common stock, net |
— |
— |
995,279 |
— |
|||||||||||
Dividends paid |
(9,303) |
(8,275) |
(26,885) |
(24,812) |
|||||||||||
Stock-based compensation tax benefit |
— |
(5,486) |
— |
— |
|||||||||||
Capitalized debt issuance costs |
— |
— |
(3,223) |
(7,838) |
|||||||||||
Other |
— |
5 |
— |
84 |
|||||||||||
Net cash provided by (used in) financing activities |
(29,303) |
28,244 |
468,171 |
252,434 |
|||||||||||
Net increase (decrease) in cash and cash equivalents |
$ |
(16,297) |
$ |
(6,459) |
$ |
500,679 |
$ |
(12,181) |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
As reported - net income (loss) |
$ |
(10,260) |
$ |
(15,514) |
$ |
(124,364) |
$ |
(2,767) |
|||||||
Reversal of selected items: |
|||||||||||||||
(Gain) loss on sale of assets |
1,245 |
(3,756) |
768 |
(3,814) |
|||||||||||
(Gain) loss on derivative instruments (1) |
(15,005) |
27,733 |
4,490 |
89,159 |
|||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Drilling rig termination fees |
(1,532) |
— |
1,655 |
5,095 |
|||||||||||
Stock-based compensation expense |
5,109 |
(2,913) |
23,016 |
11,622 |
|||||||||||
Tax effect on selected items |
3,696 |
(7,725) |
(12,572) |
(36,841) |
|||||||||||
Net income (loss) excluding selected items |
$ |
(16,747) |
$ |
(2,175) |
$ |
(102,298) |
$ |
62,454 |
|||||||
As reported - earnings (loss) per share |
$ |
(0.02) |
$ |
(0.04) |
$ |
(0.27) |
$ |
(0.01) |
|||||||
Per share impact of selected items |
(0.02) |
0.03 |
0.04 |
0.16 |
|||||||||||
Earnings (loss) per share excluding selected items |
$ |
(0.04) |
$ |
(0.01) |
$ |
(0.23) |
$ |
0.15 |
|||||||
Weighted-average common shares outstanding |
465,149 |
413,846 |
454,060 |
413,636 |
|||||||||||
(1) This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
Net income (loss) |
$ |
(10,260) |
$ |
(15,514) |
$ |
(124,364) |
$ |
(2,767) |
|||||||
Plus (less): |
|||||||||||||||
Deferred income tax expense (benefit) |
4,880 |
1,066 |
(59,413) |
8,226 |
|||||||||||
(Gain) loss on sale of assets |
1,245 |
(3,756) |
768 |
(3,814) |
|||||||||||
Exploratory dry hole cost |
— |
6 |
18 |
184 |
|||||||||||
(Gain) loss on derivative instruments |
(6,904) |
(17,364) |
1,286 |
(44,668) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
(8,101) |
45,097 |
3,204 |
133,827 |
|||||||||||
Income charges not requiring cash |
147,502 |
140,823 |
475,641 |
482,771 |
|||||||||||
Discretionary cash flow |
128,362 |
150,358 |
297,140 |
573,759 |
|||||||||||
Changes in assets and liabilities |
(22,957) |
(3,996) |
(44,491) |
11,195 |
|||||||||||
Net cash provided by operating activities |
$ |
105,405 |
$ |
146,362 |
$ |
252,649 |
$ |
584,954 |
EBITDAX Calculation and Reconciliation | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Nine Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
Net income (loss) |
$ |
(10,260) |
$ |
(15,514) |
$ |
(124,364) |
$ |
(2,767) |
|||||||
Plus (less): |
|||||||||||||||
Loss on debt extinguishment |
— |
— |
4,709 |
— |
|||||||||||
Interest expense |
21,483 |
24,510 |
67,821 |
72,244 |
|||||||||||
Income tax expense (benefit) |
(8,027) |
(10,020) |
(71,243) |
(2,169) |
|||||||||||
Depreciation, depletion and amortization |
139,490 |
144,326 |
448,910 |
472,335 |
|||||||||||
Exploration |
2,988 |
4,930 |
13,109 |
18,960 |
|||||||||||
(Gain) loss on sale of assets |
1,245 |
(3,756) |
768 |
(3,814) |
|||||||||||
Non-cash (gain) loss on derivative instruments |
(15,005) |
27,733 |
4,490 |
89,159 |
|||||||||||
(Earnings) loss on equity method investments |
1,727 |
(1,648) |
(208) |
(4,581) |
|||||||||||
Stock-based compensation |
5,109 |
(2,913) |
23,016 |
11,622 |
|||||||||||
EBITDAX |
$ |
138,750 |
$ |
167,648 |
$ |
367,008 |
$ |
650,989 |
Net Debt Reconciliation | |||||||
(In thousands) | |||||||
September 30, |
December 31, | ||||||
Current portion of long-term debt |
$ |
— |
$ |
20,000 |
|||
Long-term debt, net |
1,520,190 |
1,996,139 |
|||||
Total debt |
$ |
1,520,190 |
$ |
2,016,139 |
|||
Stockholders' equity |
2,863,250 |
2,009,188 |
|||||
Total capitalization |
$ |
4,383,440 |
$ |
4,025,327 |
|||
Total debt |
$ |
1,520,190 |
$ |
2,016,139 |
|||
Less: Cash and cash equivalents |
(501,193) |
(514) |
|||||
Net debt |
$ |
1,018,997 |
$ |
2,015,625 |
|||
Net debt |
$ |
1,018,997 |
$ |
2,015,625 |
|||
Stockholders' equity |
2,863,250 |
2,009,188 |
|||||
Total adjusted capitalization |
$ |
3,882,247 |
$ |
4,024,813 |
|||
Total debt to total capitalization ratio |
34.7 |
% |
50.1 |
% | |||
Less: Impact of cash and cash equivalents |
8.5 |
% |
— |
% | |||
Net debt to adjusted capitalization ratio |
26.2 |
% |
50.1 |
% |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 27, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of two cents ($0.02) per share on the Company's common stock. The dividend will be paid November 17, 2016 to all shareholders of record as of the close of business November 3, 2016.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas is a leading independent natural gas producer, with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 13, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today announced that the Federal Energy Regulatory Commission ("FERC") issued a letter announcing that it is evaluating certain alternatives to the Central Penn Line North and South routes, which are portions of the Atlantic Sunrise Project. The two alternative routes that are being evaluated include a potential 1.4 mile deviation, in aggregate, from the currently proposed route. Comments from the affected landowners regarding the alternative routes are due no later than November 14, 2016. Cabot anticipates that the FERC will issue an updated Notice of Schedule in a timely manner, which should address the updated timeline for the issuance of the Final Environmental Impact Statement.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Oct. 3, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its third quarter 2016 earnings conference call on Friday, October 28, 2016 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 29, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the second quarter of 2016.
"Cabot's 2016 operating plan was designed to provide modest production growth while generating positive free cash flow despite a lower commodity price environment," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our second quarter results delivered on this plan as the Company grew equivalent production 10 percent relative to the second quarter of last year while generating operating cash flow that exceeded our capital expenditures, pipeline investments, and dividends." Dinges added, "We anticipate significantly more positive free cash flow generation in the second half of the year based on the current commodity price outlook."
Second Quarter 2016 Financial Results
Equivalent production in the second quarter of 2016 was 151.8 billion cubic feet equivalent (Bcfe), consisting of 144.3 billion cubic feet (Bcf) of natural gas, 1.1 million barrels (Mmbbls) of crude oil and condensate, and 113,000 barrels (Bbls) of natural gas liquids (NGLs). The Company estimates that unscheduled downtime related to infrastructure maintenance negatively impacted natural gas production for the quarter by approximately 3.3 Bcf, or 36 million cubic feet (Mmcf) per day. "While our daily equivalent production for the quarter was in line with the mid-point of our guidance, the Company would have surpassed the high-end of our guidance range had we not experienced this unexpected downtime during the quarter," stated Dinges.
Cash flow from operating activities in the second quarter of 2016 was $85.2 million, compared to $171.2 million in the second quarter of 2015. Discretionary cash flow in the second quarter of 2016 was $97.6 million, compared to $183.2 million in the second quarter of 2015. Net loss in the second quarter of 2016 was $62.9 million, or $0.14 per share, compared to net loss of $27.5 million, or $0.07 per share, in the second quarter of 2015. Excluding the effect of selected items (detailed in the table below), net loss in the second quarter of 2016 was $30.2 million, or $0.07 per share, compared to net income of $14.6 million, or $0.03 per share, in the second quarter of 2015. EBITDAX in the second quarter of 2016 was $127.3 million, compared to $203.9 million in the second quarter of 2015. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income (loss) excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations, including the impact of derivatives, were $1.63 per thousand cubic feet (Mcf) in the second quarter of 2016, down 24 percent compared to the second quarter of 2015. Excluding the impact of derivatives, natural gas price realizations for the quarter implied a $0.40 discount to NYMEX settlement prices compared to a $0.89 discount to NYMEX settlement prices in the second quarter of 2015. Oil price realizations, including the impact of derivatives, were $40.30 per Bbl, down 28 percent compared to the second quarter of 2015. NGL price realizations were $12.43 per Bbl, down 29 percent compared to the second quarter of 2015.
Operating expenses (including financing) decreased to $2.22 per thousand cubic feet equivalent (Mcfe) in the second quarter of 2016, a 12 percent improvement compared to $2.52 per Mcfe in the second quarter of 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.19 per Mcfe in the second quarter of 2016, a 12 percent improvement compared to $1.35 per Mcfe in the second quarter of 2015.
Cabot drilled seven net wells and completed 11 net wells during the second quarter of 2016, incurring a total of $70.9 million in capital expenditures associated with activity during this period.
Year-To-Date 2016 Financial Results
Equivalent production for the six-month period ended June 30, 2016 was 312.1 Bcfe, consisting of 297.4 Bcf of natural gas, 2.2 Mmbbls of crude oil and condensate, and 205,000 Bbls of NGLs.
For the six-month period ended June 30, 2016, cash flow from operating activities was $147.2 million, compared to $438.6 million for the six-month period ended June 30, 2015. Discretionary cash flow was $168.8 million for the six-month period ended June 30, 2016, compared to $423.4 million for the six-month period ended June 30, 2015. For the six-month period ended June 30, 2016, net loss was $114.1 million, or $0.25 per share, compared to net income of $12.7 million, or $0.03 per share, for the six-month period ended June 30, 2015. Excluding the effect of selected items, net loss was $85.6 million, or $0.19 per share, compared to net income of $64.0 million, or $0.15 per share, for the six-month period ended June 30, 2015. EBITDAX for the six-month period ended June 30, 2016 was $228.3 million, compared to $483.3 million for the six-month period ended June 30, 2015.
Natural gas price realizations, including the impact of derivatives, were $1.55 per Mcf for the six-month period ended June 30, 2016, down 33 percent compared to the six-month period ended June 30, 2015. Oil price realizations, including the impact of derivatives, were $34.06 per Bbl, down 32 percent compared to the six-month period ended June 30, 2015. NGL price realizations were $10.09 per Bbl, down 29 percent compared to the six-month period ended June 30, 2015.
Operating expenses (including financing) decreased to $2.24 per Mcfe for the six-month period ended June 30, 2016, a seven percent improvement compared to $2.41 per Mcfe for the six-month period ended June 30, 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.18 per Mcfe for the six-month period ended June 30, 2016, a nine percent improvement compared to $1.30 per Mcfe in the six-month period ended June 30, 2015.
Cabot drilled 17 net wells and completed 32 net wells during the six-month period ended June 30, 2016, incurring a total of $162.5 million in capital expenditures associated with activity during this period.
Operational Highlights
Marcellus Shale
During the second quarter of 2016, the Company averaged 1,535 Mmcf per day of net Marcellus production (1,798 gross operated Mmcf per day), an increase of 14 percent compared to the second quarter of 2015. During the second quarter, the Company drilled seven net wells, completed eight net wells and placed 12 net wells on production including a four-well pad that was placed on production 10 days prior to the quarter-end and had minimal impact on second quarter production as the wells were still cleaning up in line.
Cabot is currently operating one rig and recently added a second completion crew in the Marcellus Shale. "Based on continued efficiency gains, lower service costs and our improved outlook for natural gas price realizations, we are increasing our activity levels in our high-return Marcellus asset beginning with the addition of a second completion crew." Dinges added, "Cabot is the lowest cost producer in Northeast Pennsylvania and generates rates of return over 100 percent under current price expectations so we plan to opportunistically increase our market share during 2017 as we await the in-service of our new infrastructure projects beginning in late-2017."
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the second quarter of 2016 was 14,312 barrels of oil equivalent (Boe) per day, an increase of 10 percent sequentially compared to the first quarter of 2016. Net oil production during the quarter was 12,360 Bbls per day, an increase of four percent sequentially compared to the first quarter of 2016. During the second quarter, the Company did not drill any wells; however, Cabot completed and placed on production three net wells.
Cabot plans to drill two Eagle Ford wells during the third quarter and will not complete or place on production an additional Eagle Ford well until the fourth quarter.
Financial Position and Liquidity
As of June 30, 2016, Cabot had total debt of $1.5 billion and cash on hand of $517.5 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 26.2 percent and 1.8x, respectively, compared to 50.1 percent and 2.5x as of December 31, 2015.
Total commitments under the Company's revolving credit facility remain unchanged at $1.8 billion, with approximately $1.7 billion currently available to the Company. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity.
Third Quarter and Full-Year 2016 Guidance
Cabot has provided third quarter net production guidance of 1,575 to 1,600 Mmcf per day for natural gas; 10,000 to 10,500 Bbls per day for crude oil and condensate; and 1,200 to 1,250 Bbls per day for NGLs. The Company expects its natural gas price realizations (before the impact of derivatives) to average between $0.80 and $0.90 below NYMEX settlement prices for the third quarter based on the assumption of an average NYMEX settlement price of approximately $2.80. "Despite a widening of basis in the third quarter due to higher NYMEX prices, our natural gas price realizations before the impact of derivatives are forecasted to be over 25 percent higher than our second quarter realizations based on the mid-point of our differential guidance,'' commented Dinges.
Cabot has increased its 2016 capital budget from $325 million to $345 million to reflect the incremental capital for the completion of an additional 15 to 20 net wells during the second half of the year, partially offset by efficiency gains and cost savings realized throughout the year. Since the production impact from these additional wells will not be realized until early 2017, the Company's 2016 production growth guidance range of two to seven percent remains unchanged. For further disclosure on Cabot's natural gas pricing exposure by index and updated unit cost guidance for the third quarter, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call
A conference call is scheduled for Friday, July 29, 2016, at 9:30 a.m. Eastern Time to discuss second quarter 2016 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website. The latest financial guidance, including the Company's derivative positions, is also available in the Investor Relations section of the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
PRODUCTION VOLUMES |
|||||||||||||||
Natural gas (Bcf) |
144.3 |
128.4 |
297.4 |
290.2 |
|||||||||||
Crude oil and condensate (Mbbl) |
1,139.3 |
1,447.9 |
2,248.9 |
2,875.5 |
|||||||||||
Natural gas liquids (NGLs) (Mbbl) |
112.9 |
164.2 |
205.0 |
330.1 |
|||||||||||
Equivalent production (Bcfe) |
151.8 |
138.0 |
312.1 |
309.4 |
|||||||||||
AVERAGE SALES PRICE |
|||||||||||||||
Natural gas, including hedges ($/Mcf) |
$ |
1.63 |
$ |
2.15 |
$ |
1.55 |
$ |
2.32 |
|||||||
Natural gas, excluding hedges ($/Mcf) |
$ |
1.55 |
$ |
1.75 |
$ |
1.52 |
$ |
2.02 |
|||||||
Crude oil and condensate, including hedges ($/Bbl) |
$ |
40.30 |
$ |
56.10 |
$ |
34.06 |
$ |
50.00 |
|||||||
Crude oil and condensate, excluding hedges ($/Bbl) |
$ |
40.51 |
$ |
56.10 |
$ |
34.16 |
$ |
50.00 |
|||||||
NGL ($/Bbl) |
$ |
12.43 |
$ |
17.44 |
$ |
10.09 |
$ |
14.23 |
|||||||
AVERAGE UNIT COSTS ($/Mcfe) |
|||||||||||||||
Direct operations |
$ |
0.17 |
$ |
0.26 |
$ |
0.17 |
$ |
0.23 |
|||||||
Transportation and gathering |
0.71 |
0.71 |
0.70 |
0.71 |
|||||||||||
Taxes other than income |
0.06 |
0.08 |
0.05 |
0.07 |
|||||||||||
Exploration |
0.02 |
0.04 |
0.03 |
0.05 |
|||||||||||
Depreciation, depletion and amortization |
0.97 |
1.10 |
0.99 |
1.06 |
|||||||||||
General and administrative (excluding stock-based compensation) |
0.09 |
0.08 |
0.10 |
0.09 |
|||||||||||
Stock-based compensation |
0.05 |
0.06 |
0.06 |
0.05 |
|||||||||||
Interest expense |
0.14 |
0.18 |
0.15 |
0.15 |
|||||||||||
$ |
2.22 |
$ |
2.52 |
$ |
2.24 |
$ |
2.41 |
||||||||
WELLS DRILLED |
|||||||||||||||
Gross |
7 |
44 |
17 |
87 |
|||||||||||
Net |
7 |
37 |
17 |
78 |
|||||||||||
Gross success rate |
100% |
100% |
100% |
100% |
|||||||||||
WELLS COMPLETED |
|||||||||||||||
Gross |
11 |
36 |
32 |
75 |
|||||||||||
Net |
11 |
33 |
32 |
72 |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
OPERATING REVENUES |
|||||||||||||||
Natural gas |
$ |
223,232 |
$ |
224,806 |
$ |
450,811 |
$ |
584,997 |
|||||||
Crude oil and condensate |
46,156 |
81,233 |
76,833 |
143,791 |
|||||||||||
Gain (loss) on derivative instruments |
(27,184) |
(6,819) |
(8,190) |
27,304 |
|||||||||||
Brokered natural gas |
2,596 |
3,813 |
5,776 |
8,640 |
|||||||||||
Other |
2,016 |
3,264 |
3,527 |
6,330 |
|||||||||||
246,816 |
306,297 |
528,757 |
771,062 |
||||||||||||
OPERATING EXPENSES |
|||||||||||||||
Direct operations |
26,477 |
36,112 |
52,513 |
72,129 |
|||||||||||
Transportation and gathering |
107,560 |
98,295 |
217,213 |
219,531 |
|||||||||||
Brokered natural gas |
2,021 |
2,885 |
4,587 |
6,624 |
|||||||||||
Taxes other than income |
8,973 |
11,611 |
14,967 |
22,891 |
|||||||||||
Exploration |
3,738 |
5,298 |
10,121 |
14,030 |
|||||||||||
Depreciation, depletion and amortization |
147,533 |
152,513 |
309,420 |
328,009 |
|||||||||||
General and administrative (excluding stock-based compensation) |
12,946 |
11,354 |
30,715 |
27,972 |
|||||||||||
Stock-based compensation(1) |
7,301 |
8,624 |
17,906 |
14,535 |
|||||||||||
316,549 |
326,692 |
657,442 |
705,721 |
||||||||||||
Earnings (loss) on equity method investments |
(73) |
1,512 |
1,935 |
2,933 |
|||||||||||
Gain (loss) on sale of assets |
(878) |
(79) |
477 |
59 |
|||||||||||
INCOME (LOSS) FROM OPERATIONS |
(70,684) |
(18,962) |
(126,273) |
68,333 |
|||||||||||
Loss on debt extinguishment |
4,709 |
— |
4,709 |
— |
|||||||||||
Interest expense |
21,963 |
24,168 |
46,338 |
47,734 |
|||||||||||
Income (loss) before income taxes |
(97,356) |
(43,130) |
(177,320) |
20,599 |
|||||||||||
Income tax expense (benefit) |
(34,446) |
(15,622) |
(63,216) |
7,852 |
|||||||||||
NET INCOME (LOSS) |
$ |
(62,910) |
$ |
(27,508) |
$ |
(114,104) |
$ |
12,747 |
|||||||
Earnings (loss) per share - Basic |
$ |
(0.14) |
$ |
(0.07) |
$ |
(0.25) |
$ |
0.03 |
|||||||
Weighted-average common shares outstanding |
465,068 |
413,713 |
448,455 |
413,530 |
(1) |
Includes the impact of the Company's performance share awards, restricted stock, stock appreciation rights and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | |||||||
June 30, |
December 31, | ||||||
ASSETS |
|||||||
Current assets |
$ |
659,238 |
$ |
144,786 |
|||
Properties and equipment, net (Successful efforts method) |
4,762,680 |
4,976,879 |
|||||
Other assets |
148,552 |
131,373 |
|||||
$ |
5,570,470 |
$ |
5,253,038 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
228,490 |
$ |
235,552 |
|||
Long-term debt, net (excluding current maturities) |
1,519,849 |
1,996,139 |
|||||
Deferred income taxes |
745,085 |
807,236 |
|||||
Other liabilities |
199,447 |
204,923 |
|||||
Stockholders' equity |
2,877,599 |
2,009,188 |
|||||
$ |
5,570,470 |
$ |
5,253,038 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||||||||||
Net income (loss) |
$ |
(62,910) |
$ |
(27,508) |
$ |
(114,104) |
$ |
12,747 |
|||||||
Deferred income tax expense (benefit) |
(35,322) |
(7,921) |
(64,294) |
7,160 |
|||||||||||
(Gain) loss on sale of assets |
878 |
79 |
(477) |
(59) |
|||||||||||
Exploratory dry hole cost |
18 |
16 |
18 |
178 |
|||||||||||
(Gain) loss on derivative instruments |
27,184 |
6,819 |
8,190 |
(27,304) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
11,305 |
51,045 |
11,305 |
88,730 |
|||||||||||
Income charges not requiring cash |
156,465 |
160,694 |
328,140 |
341,948 |
|||||||||||
Changes in assets and liabilities |
(12,464) |
(12,014) |
(21,534) |
15,191 |
|||||||||||
Net cash provided by operating activities |
85,154 |
171,210 |
147,244 |
438,591 |
|||||||||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||||||||||
Capital expenditures |
(67,162) |
(250,001) |
(159,399) |
(645,092) |
|||||||||||
Acquisitions |
— |
(16,149) |
— |
(16,300) |
|||||||||||
Proceeds from sale of assets |
— |
(79) |
49,828 |
3,002 |
|||||||||||
Investment in equity method investments |
(6,519) |
(5,036) |
(18,171) |
(10,114) |
|||||||||||
Net cash used in investing activities |
(73,681) |
(271,265) |
(127,742) |
(668,504) |
|||||||||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||||||||||
Net increase (decrease) in debt |
(64,000) |
118,000 |
(477,000) |
243,000 |
|||||||||||
Sale of common stock, net |
1 |
— |
995,279 |
— |
|||||||||||
Dividends paid |
(9,300) |
(8,274) |
(17,582) |
(16,537) |
|||||||||||
Stock-based compensation tax benefit |
— |
2,049 |
— |
5,486 |
|||||||||||
Capitalized debt issuance costs |
— |
(7,838) |
(3,223) |
(7,838) |
|||||||||||
Other |
— |
(2,599) |
— |
79 |
|||||||||||
Net cash provided by (used in) financing activities |
(73,299) |
101,338 |
497,474 |
224,190 |
|||||||||||
Net increase (decrease) in cash and cash equivalents |
$ |
(61,826) |
$ |
1,283 |
$ |
516,976 |
$ |
(5,723) |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
As reported - net income (loss) |
$ |
(62,910) |
$ |
(27,508) |
$ |
(114,104) |
$ |
12,747 |
|||||||
Reversal of selected items: |
|||||||||||||||
(Gain) loss on sale of assets |
878 |
79 |
(477) |
(59) |
|||||||||||
(Gain) loss on derivative instruments (1) |
38,489 |
57,864 |
19,495 |
61,426 |
|||||||||||
Loss on debt extinguishment |
4,709 |
— |
4,709 |
— |
|||||||||||
Drilling rig termination fees |
— |
69 |
3,188 |
5,153 |
|||||||||||
Stock-based compensation expense |
7,301 |
8,624 |
17,906 |
14,535 |
|||||||||||
Tax effect on selected items |
(18,647) |
(24,553) |
(16,268) |
(29,836) |
|||||||||||
Net income (loss) excluding selected items |
$ |
(30,180) |
$ |
14,575 |
$ |
(85,551) |
$ |
63,966 |
|||||||
As reported - earnings (loss) per share |
$ |
(0.14) |
$ |
(0.07) |
$ |
(0.25) |
$ |
0.03 |
|||||||
Per share impact of reversing selected items |
0.07 |
0.10 |
0.06 |
0.12 |
|||||||||||
Earnings (loss) per share including reversal of selected items |
$ |
(0.07) |
$ |
0.03 |
$ |
(0.19) |
$ |
0.15 |
|||||||
Weighted average common shares outstanding |
465,068 |
413,713 |
448,455 |
413,530 |
(1) |
This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
As reported - net income (loss) |
$ |
(62,910) |
$ |
(27,508) |
$ |
(114,104) |
$ |
12,747 |
|||||||
Plus (less): |
|||||||||||||||
Deferred income tax expense (benefit) |
(35,322) |
(7,921) |
(64,294) |
7,160 |
|||||||||||
(Gain) loss on sale of assets |
878 |
79 |
(477) |
(59) |
|||||||||||
Exploratory dry hole cost |
18 |
16 |
18 |
178 |
|||||||||||
(Gain) loss on derivative instruments |
27,184 |
6,819 |
8,190 |
(27,304) |
|||||||||||
Net cash received (paid) in settlement of derivative instruments |
11,305 |
51,045 |
11,305 |
88,730 |
|||||||||||
Income charges not requiring cash |
156,465 |
160,694 |
328,140 |
341,948 |
|||||||||||
Discretionary cash flow |
97,618 |
183,224 |
168,778 |
423,400 |
|||||||||||
Changes in assets and liabilities |
(12,464) |
(12,014) |
(21,534) |
15,191 |
|||||||||||
Net cash provided by operations |
$ |
85,154 |
$ |
171,210 |
$ |
147,244 |
$ |
438,591 |
EBITDAX Calculation and Reconciliation | |||||||||||||||
(In thousands) | |||||||||||||||
Quarter Ended |
Six Months Ended | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
As reported - net income (loss) |
$ |
(62,910) |
$ |
(27,508) |
$ |
(114,104) |
$ |
12,747 |
|||||||
Plus (less): |
|||||||||||||||
Loss on debt extinguishment |
4,709 |
— |
4,709 |
— |
|||||||||||
Interest expense |
21,963 |
24,168 |
46,338 |
47,734 |
|||||||||||
Income tax expense (benefit) |
(34,446) |
(15,622) |
(63,216) |
7,852 |
|||||||||||
Depreciation, depletion and amortization |
147,533 |
152,513 |
309,420 |
328,009 |
|||||||||||
Exploration |
3,738 |
5,298 |
10,121 |
14,030 |
|||||||||||
(Gain) loss on sale of assets |
878 |
79 |
(477) |
(59) |
|||||||||||
Non-cash (gain) loss on derivative instruments |
38,489 |
57,864 |
19,495 |
61,426 |
|||||||||||
(Earnings) loss on equity method investments |
73 |
(1,512) |
(1,935) |
(2,933) |
|||||||||||
Stock-based compensation |
7,301 |
8,624 |
17,906 |
14,535 |
|||||||||||
EBITDAX |
$ |
127,328 |
$ |
203,904 |
$ |
228,257 |
$ |
483,341 |
Net Debt Reconciliation | |||||||
(In thousands) | |||||||
June 30, |
December 31, | ||||||
Current portion of long-term debt |
$ |
20,000 |
$ |
20,000 |
|||
Long-term debt, net |
1,519,849 |
1,996,139 |
|||||
Total debt |
$ |
1,539,849 |
$ |
2,016,139 |
|||
Stockholders' equity |
2,877,599 |
2,009,188 |
|||||
Total capitalization |
$ |
4,417,448 |
$ |
4,025,327 |
|||
Total debt |
$ |
1,539,849 |
$ |
2,016,139 |
|||
Less: Cash and cash equivalents |
(517,490) |
(514) |
|||||
Net debt |
$ |
1,022,359 |
$ |
2,015,625 |
|||
Net debt |
$ |
1,022,359 |
$ |
2,015,625 |
|||
Stockholders' equity |
2,877,599 |
2,009,188 |
|||||
Total adjusted capitalization |
$ |
3,899,958 |
$ |
4,024,813 |
|||
Total debt to total capitalization ratio |
34.9% |
50.1% |
|||||
Less: Impact of cash and cash equivalents |
8.7% |
—% |
|||||
Net debt to adjusted capitalization ratio |
26.2% |
50.1% |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 27, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of two cents ($0.02) per share on the Company's common stock. The dividend will be paid August 24, 2016 to all shareholders of record as of the close of business August 10, 2016.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 6, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its second quarter 2016 earnings conference call on Friday, July 29, 2016 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, July 5, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot") today reported it has executed a 10-year sales agreement to be the exclusive provider of natural gas supplies to Invenergy LLC's Lackawanna Energy Center power plant. Additionally, South Jersey Industries (NYSE: SJI) ("SJI"), the energy holding company for South Jersey Resources Group, LLC, will become a counterparty to both entities through an exclusive supply fuel management service agreement.
The proposed facility is a natural-gas fueled 1,500 megawatt combined-cycle generating station located in Lackawanna County, Pennsylvania and is expected to be one of the most efficient power plants in the United States. Commercial operations are expected to begin in mid-2018 and to reach full-scale operations by year-end 2018. The facility, at maximum capacity, will burn up to 240,000 dekatherms of natural gas per day. Confidential pricing terms under the agreement guarantee Cabot attractive rates of return while providing fuel costs directly linked to power prices, eliminating risks for each of the parties involved in the transaction.
"We are very pleased to finalize this agreement with SJI and to provide locally produced natural gas to this state-of-the-art power generation facility," commented Dan O. Dinges, Chairman, President and Chief Executive Officer. "Together with our previously announced agreement with SJI to supply natural gas to the Caithness Moxie Freedom project, Cabot will be providing more than 400,000 dekatherms of natural gas per day for power generation directly in our backyard."
About Cabot Oil & Gas Corporation
Cabot Oil & Gas Corporation (NYSE: COG), headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
About South Jersey Industries
South Jersey Industries (NYSE: SJI), an energy services holding company based in Folsom, NJ, operates its business through two primary subsidiaries. South Jersey Gas delivers clean, efficient natural gas and promotes energy efficiency to approximately 375,000 customers in southern New Jersey. SJI's non-regulated businesses, under South Jersey Energy Solutions, promote efficiency, clean technology and renewable energy by developing, owning and operating on-site energy production facilities; acquiring and marketing natural gas and electricity for retail customers; providing wholesale commodity marketing and fuel management services; and offering HVAC and other energy-efficiency related services. For more information about SJI and its subsidiaries, visit www.sjindustries.com.
About Invenergy
Invenergy is delivering innovation in energy. Invenergy and its affiliated companies develop, own, and operate large-scale renewable and other clean energy generation and storage facilities in the Americas, and Europe. Invenergy's home office is located in Chicago and it has regional development offices in the United States, Canada, Mexico, Japan and Europe.
Invenergy and its affiliated companies have developed more than 13,719 MW of projects that are in operation, construction or advanced development, including wind, solar, natural gas-fueled power generation and energy storage projects. For more information, please visit www.invenergyllc.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, May 4, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) today announced that its Board of Directors declared a regular dividend of two cents ($0.02) per share on the Company's common stock. The dividend will be paid May 31, 2016 to all shareholders of record as of the close of business May 16, 2016.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 29, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today reported financial and operating results for the first quarter of 2016.
"Cabot's results for the quarter highlight our commitment to financial discipline, which was evident by our ability to fully fund our investing activities with operating cash flow and proceeds from a non-core divestiture," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our positive results for the quarter were due in large part to continued enhancements to our industry-leading cost structure and improvements in our natural gas price differentials, which exceeded our expectations for the quarter. Based on our current outlook for the remainder of the year, we are well-positioned to deliver production growth while spending within our operating cash flow, which differentiates Cabot in this challenged market environment."
First Quarter 2016 Financial Results
Equivalent production in the first quarter of 2016 was 160.3 billion cubic feet equivalent (Bcfe), consisting of 153.1 billion cubic feet (Bcf) of natural gas, 1.1 million barrels (Mmbbls) of crude oil and condensate, and 92,000 barrels (Bbls) of natural gas liquids (NGLs).
Cash flow from operations in the first quarter of 2016 was $62.1 million, compared to $267.4 million in the first quarter of 2015. Discretionary cash flow in the first quarter of 2016 was $71.2 million, compared to $240.2 million in the first quarter of 2015. Net loss in the first quarter of 2016 was $51.2 million, or $0.12 per share, compared to net income of $40.3 million, or $0.10 per share, in the first quarter of 2015. Excluding the effect of selected items (detailed in the table below), net loss in the first quarter of 2016 was $55.4 million, or $0.13 per share, compared to net income of $49.2 million, or $0.12 per share, in the first quarter of 2015. EBITDAX in the first quarter of 2016 was $100.9 million, compared to $279.4 million in the first quarter of 2015. See the supplemental tables at the end of this press release for a reconciliation of non-GAAP measures including discretionary cash flow, net income excluding selected items, EBITDAX and net debt to adjusted capitalization ratio.
Natural gas price realizations were $1.49 per thousand cubic feet (Mcf) in the first quarter of 2016, down 39 percent compared to the first quarter of 2015. Natural gas price realizations for the quarter implied a $0.60 discount to NYMEX settlement prices compared to a $0.75 discount to NYMEX settlement prices in the first quarter of 2015 (excluding the impact of hedges). Oil price realizations were $27.65 per Bbl, down 37 percent compared to the first quarter of 2015. NGL price realizations were $7.22 per Bbl, down 35 percent compared to the first quarter of 2015.
Operating expenses (including financing) decreased to $2.26 per thousand cubic feet equivalent (Mcfe) in the first quarter of 2016, a 3 percent improvement compared to $2.33 per Mcfe in the first quarter of 2015. Cash operating expenses (excluding depreciation, depletion and amortization; stock-based compensation; exploratory dry hole cost; and amortization of debt issuance costs) decreased to $1.18 per Mcfe in the first quarter of 2016, a 6 percent improvement compared to $1.26 per Mcfe in the first quarter of 2015.
Cabot drilled 10 net wells and completed 21 net wells during the first quarter of 2016, incurring a total of $91.7 million in capital expenditures associated with activity during this period.
Operational Highlights
Marcellus Shale
During the first quarter of 2016, the Company averaged 1,628 million cubic feet (Mmcf) per day of net Marcellus production (1,913 gross operated Mmcf per day), an increase of 10 percent sequentially compared to the fourth quarter of 2015. During the first quarter, the Company drilled 7 net wells, completed 12 net wells and placed 8 net wells on production.
Cabot is currently operating 1 rig in the Marcellus Shale and plans to remain at this level for the remainder of the year.
Eagle Ford Shale
Cabot's net production in the Eagle Ford Shale during the first quarter of 2016 was 12,975 barrels of oil equivalent (Boe) per day, a decrease of 13 percent sequentially compared to the fourth quarter of 2015. Net oil production during the quarter was 11,908 Bbls per day, a decrease of 6 percent sequentially compared to the fourth quarter of 2015. In addition to natural production declines resulting from reduced operating activity, the primary driver of the lower sequential equivalent production was unscheduled downtime at a third-party processing plant which impacted natural gas and NGL volumes for a significant portion of the quarter. During the first quarter, the Company drilled 3 net wells and completed and placed on production 9 net wells, the majority of which were placed on production late in the quarter.
Cabot is not currently operating a rig in the Eagle Ford Shale and plans to drill 3 additional wells in 2016, all of which are scheduled for the second half of the year.
Non-Core Asset Sale
During the first quarter of 2016, the Company completed the divestiture of certain non-core oil and gas properties in East Texas to an undisclosed buyer for approximately $57 million. At December 31, 2015, proved reserves associated with these properties were 16.7 Bcfe (80% natural gas / 15% NGLs / 5% oil).
Financial Position and Liquidity
During the first quarter of 2016, Cabot closed on an offering of 50.6 million shares of its common stock (including the over-allotment option) for net proceeds of $995.6 million. The Company used a portion of the net proceeds to repay borrowings outstanding under its revolving credit facility.
As of March 31, 2016, Cabot had total debt of $1.6 billion and cash on hand of $579.3 million. The Company's net debt to adjusted capitalization ratio and net debt to trailing twelve months EBITDAX ratio were 25.8 percent and 1.6x, respectively, compared to 50.1 percent and 2.5x as of December 31, 2015.
Effective April 19, 2016, Cabot's borrowing base was unanimously approved by its 20 lenders at $3.2 billion. With $1.6 billion of senior notes outstanding, this leaves the Company with approximately $1.6 billion of available commitments under the $1.8 billion credit facility. The Company currently has no debt outstanding under the credit facility, resulting in approximately $2.2 billion of liquidity. Cabot's next annual borrowing base redetermination is scheduled for April 2017.
2016 Derivative Position Update
The Company has approximately 52 Bcf of natural gas swaps for the period of April to October 2016 at a weighted average price of approximately $2.51 per Mcf and 1.4 Mmbbls of crude oil collars for the period of April to December 2016 at a weighted average floor and ceiling price of $38.00 per Bbl and $47.28 per Bbl, respectively.
Second Quarter and Full Year 2016 Guidance
Cabot has provided second quarter net production guidance of 1,575 to 1,600 Mmcf per day for natural gas; 11,500 to 12,250 Bbls per day for crude oil and condensate; and 1,400 to 1,600 Bbls per day for NGLs. The Company expects its natural gas price realizations (before the impact of hedges) to average between $0.50 and $0.55 below NYMEX settlement prices for the second quarter based on current market indications.
Cabot has reaffirmed its $325 million capital budget and its production growth guidance range of 2 to 7 percent for 2016. The Company has also adjusted its 2016 guidance range for contributions to its equity method investments in the Constitution and Atlantic Sunrise pipelines to $30 million to $35 million, down from $80 million to $150 million, to reflect the current expectation for a second half of 2017 in-service date for Atlantic Sunrise and a second half of 2018 in-service date for Constitution. For further disclosure on Cabot's natural gas pricing exposure by index and updated unit cost guidance for the second quarter, please see the current Guidance slide in the Investor Relations section of the Company's website.
Conference Call
A conference call is scheduled for Friday, April 29, 2016, at 9:30 a.m. Eastern Time to discuss first quarter 2016 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website. The latest financial guidance, including the Company's hedge positions, is also available in the Investor Relations section of the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
OPERATING DATA | ||||||||
Three Months Ended | ||||||||
2016 |
2015 | |||||||
PRODUCTION VOLUMES |
||||||||
Natural gas (Bcf) |
153.1 |
161.8 |
||||||
Crude/condensate (Mbbl) |
1,110.0 |
1,428.0 |
||||||
Natural gas liquids (NGLs) (Mbbl) |
92.0 |
166.0 |
||||||
Equivalent production (Bcfe) |
160.3 |
171.4 |
||||||
AVERAGE SALES PRICE |
||||||||
Natural gas, including hedges ($/Mcf) |
$ |
1.49 |
$ |
2.46 |
||||
Natural gas, excluding hedges ($/Mcf) |
$ |
1.49 |
$ |
2.23 |
||||
Crude/condensate, including hedges ($/Bbl) |
$ |
27.65 |
$ |
43.82 |
||||
Crude/condensate, excluding hedges ($/Bbl) |
$ |
27.65 |
$ |
43.82 |
||||
NGL ($/Bbl) |
$ |
7.22 |
$ |
11.06 |
||||
AVERAGE UNIT COSTS ($/Mcfe) |
||||||||
Direct operations |
$ |
0.16 |
$ |
0.21 |
||||
Transportation and gathering |
0.68 |
0.71 |
||||||
Taxes other than income |
0.04 |
0.07 |
||||||
Exploration |
0.04 |
0.05 |
||||||
Depreciation, depletion and amortization |
1.01 |
1.02 |
||||||
General and administrative (excluding stock-based compensation) |
0.11 |
0.10 |
||||||
Stock-based compensation |
0.07 |
0.03 |
||||||
Interest expense |
0.15 |
0.14 |
||||||
$ |
2.26 |
$ |
2.33 |
|||||
WELLS DRILLED |
||||||||
Gross |
10 |
43 |
||||||
Net |
10 |
42 |
||||||
Gross success rate |
100 |
% |
100 |
% | ||||
WELLS COMPLETED |
||||||||
Gross |
21 |
39 |
||||||
Net |
21 |
39 |
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS (Unaudited) | |||||||
(In thousands, except per share amounts) | |||||||
Three Months Ended | |||||||
2016 |
2015 | ||||||
OPERATING REVENUES |
|||||||
Natural gas |
$ |
227,578 |
$ |
360,191 |
|||
Crude oil and condensate |
30,676 |
62,558 |
|||||
Gain (loss) on derivative instruments |
18,994 |
34,123 |
|||||
Brokered natural gas |
3,180 |
4,827 |
|||||
Other |
1,513 |
3,066 |
|||||
281,941 |
464,765 |
||||||
OPERATING EXPENSES |
|||||||
Direct operations |
26,035 |
36,017 |
|||||
Transportation and gathering |
109,652 |
121,235 |
|||||
Brokered natural gas |
2,566 |
3,739 |
|||||
Taxes other than income |
5,994 |
11,280 |
|||||
Exploration |
6,383 |
8,732 |
|||||
Depreciation, depletion and amortization |
161,887 |
175,497 |
|||||
General and administrative (excluding stock-based compensation) |
17,770 |
16,619 |
|||||
Stock-based compensation(1) |
10,606 |
5,910 |
|||||
340,893 |
379,029 |
||||||
Earnings (loss) on equity method investments |
2,009 |
1,421 |
|||||
Gain (loss) on sale of assets |
1,354 |
138 |
|||||
INCOME (LOSS) FROM OPERATIONS |
(55,589) |
87,295 |
|||||
Interest expense |
24,375 |
23,566 |
|||||
Income (loss) before income taxes |
(79,964) |
63,729 |
|||||
Income tax expense (benefit) |
(28,770) |
23,474 |
|||||
NET INCOME (LOSS) |
$ |
(51,194) |
$ |
40,255 |
|||
Earnings (loss) per share - Basic |
$ |
(0.12) |
$ |
0.10 |
|||
Weighted-average common shares outstanding |
431,841 |
413,344 |
(1) |
Includes the impact of the Company's performance share awards, restricted stock, stock appreciation rights and expense associated with the Supplemental Employee Incentive Plan. |
CONDENSED CONSOLIDATED BALANCE SHEET (Unaudited) | |||||||
(In thousands) | |||||||
March 31, |
December 31, | ||||||
ASSETS |
|||||||
Current assets |
$ |
720,687 |
$ |
144,786 |
|||
Properties and equipment, net (Successful efforts method) |
4,837,814 |
4,976,879 |
|||||
Other assets |
144,207 |
131,373 |
|||||
$ |
5,702,708 |
$ |
5,253,038 |
||||
LIABILITIES AND STOCKHOLDERS' EQUITY |
|||||||
Current liabilities |
$ |
199,382 |
$ |
235,552 |
|||
Long-term debt, net (excluding current maturities) |
1,583,192 |
1,996,139 |
|||||
Deferred income taxes |
780,295 |
807,236 |
|||||
Other liabilities |
195,779 |
204,923 |
|||||
Stockholders' equity |
2,944,060 |
2,009,188 |
|||||
$ |
5,702,708 |
$ |
5,253,038 |
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited) | |||||||
(In thousands) | |||||||
Three Months Ended | |||||||
2016 |
2015 | ||||||
CASH FLOWS FROM OPERATING ACTIVITIES |
|||||||
Net income (loss) |
$ |
(51,194) |
$ |
40,255 |
|||
Deferred income tax expense (benefit) |
(28,973) |
15,081 |
|||||
(Gain) loss on sale of assets |
(1,354) |
(138) |
|||||
Exploratory dry hole cost |
— |
162 |
|||||
(Gain) loss on derivative instruments |
(18,994) |
(34,123) |
|||||
Net cash received (paid) in settlement of derivative instruments |
— |
37,685 |
|||||
Income charges not requiring cash |
171,675 |
181,254 |
|||||
Changes in assets and liabilities |
(9,070) |
27,205 |
|||||
Net cash provided by operating activities |
62,090 |
267,381 |
|||||
CASH FLOWS FROM INVESTING ACTIVITIES |
|||||||
Capital expenditures |
(92,237) |
(395,242) |
|||||
Proceeds from sale of assets |
49,828 |
3,081 |
|||||
Investment in equity method investments |
(11,652) |
(5,078) |
|||||
Net cash used in investing activities |
(54,061) |
(397,239) |
|||||
CASH FLOWS FROM FINANCING ACTIVITIES |
|||||||
Net increase (decrease) in debt |
(413,000) |
125,000 |
|||||
Sale of common stock, net |
995,278 |
— |
|||||
Dividends paid |
(8,282) |
(8,263) |
|||||
Stock-based compensation tax benefit |
— |
3,437 |
|||||
Capitalized debt issuance costs |
(3,223) |
— |
|||||
Other |
— |
2,678 |
|||||
Net cash provided by financing activities |
570,773 |
122,852 |
|||||
Net increase (decrease) in cash and cash equivalents |
$ |
578,802 |
$ |
(7,006) |
Selected Item Review and Reconciliation of Net Income and Earnings Per Share | |||||||
(In thousands, except per share amounts) | |||||||
Three Months Ended | |||||||
2016 |
2015 | ||||||
As reported - net income (loss) |
$ |
(51,194) |
$ |
40,255 |
|||
Reversal of selected items, net of tax: |
|||||||
(Gain) loss on sale of assets |
(862) |
(87) |
|||||
(Gain) loss on derivative instruments (1) |
(12,087) |
2,246 |
|||||
Drilling rig termination fees |
2,028 |
3,059 |
|||||
Stock-based compensation expense |
6,749 |
3,726 |
|||||
Net income (loss) excluding selected items |
$ |
(55,366) |
$ |
49,199 |
|||
As reported - earnings (loss) per share |
$ |
(0.12) |
$ |
0.10 |
|||
Per share impact of reversing selected items |
(0.01) |
0.02 |
|||||
Earnings per share including reversal of selected items |
$ |
(0.13) |
$ |
0.12 |
|||
Weighted average common shares outstanding |
431,841 |
413,344 |
(1) |
This amount represents the non-cash mark-to-market changes of our commodity derivative instruments recorded in gain (loss) on derivative instruments in the Condensed Consolidated Statement of Operations. |
Discretionary Cash Flow Calculation and Reconciliation | |||||||
(In thousands) | |||||||
Three Months Ended | |||||||
2016 |
2015 | ||||||
As reported - net income (loss) |
$ |
(51,194) |
$ |
40,255 |
|||
Plus (less): |
|||||||
Deferred income tax expense (benefit) |
(28,973) |
15,081 |
|||||
(Gain) loss on sale of assets |
(1,354) |
(138) |
|||||
Exploratory dry hole cost |
— |
162 |
|||||
(Gain) loss on derivative instruments |
(18,994) |
(34,123) |
|||||
Net cash received (paid) in settlement of derivative instruments |
— |
37,685 |
|||||
Income charges not requiring cash |
171,675 |
181,254 |
|||||
Discretionary Cash Flow |
71,160 |
240,176 |
|||||
Changes in assets and liabilities |
(9,070) |
27,205 |
|||||
Net cash provided by operations |
$ |
62,090 |
$ |
267,381 |
EBITDAX Calculation and Reconciliation | |||||||
(in thousands) | |||||||
Three Months Ended | |||||||
2016 |
2015 | ||||||
As reported - net income (loss) |
$ |
(51,194) |
$ |
40,255 |
|||
Plus (less): |
|||||||
Interest expense |
24,375 |
23,566 |
|||||
Income tax expense (benefit) |
(28,770) |
23,474 |
|||||
Depreciation, depletion and amortization |
161,887 |
175,497 |
|||||
Exploration |
6,383 |
8,732 |
|||||
(Gain) loss on sale of assets |
(1,354) |
(138) |
|||||
Non-cash (gain) loss on derivative instruments |
(18,994) |
3,562 |
|||||
(Earnings) loss on equity method investments |
(2,009) |
(1,421) |
|||||
Stock-based compensation |
10,606 |
5,910 |
|||||
EBITDAX |
$ |
100,930 |
$ |
279,437 |
Net Debt Reconciliation | |||||||
(In thousands) | |||||||
March 31, |
December 31, | ||||||
Current portion of long-term debt |
$ |
20,000 |
$ |
20,000 |
|||
Long-term debt, net |
1,583,192 |
1,996,139 |
|||||
Total debt |
$ |
1,603,192 |
$ |
2,016,139 |
|||
Stockholders' equity |
2,944,060 |
2,009,188 |
|||||
Total Capitalization |
$ |
4,547,252 |
$ |
4,025,327 |
|||
Total debt |
$ |
1,603,192 |
$ |
2,016,139 |
|||
Less: Cash and cash equivalents |
(579,316) |
(514) |
|||||
Net Debt |
$ |
1,023,876 |
$ |
2,015,625 |
|||
Net debt |
$ |
1,023,876 |
$ |
2,015,625 |
|||
Stockholders' equity |
2,944,060 |
2,009,188 |
|||||
Total Adjusted Capitalization |
$ |
3,967,936 |
$ |
4,024,813 |
|||
Total debt to total capitalization ratio |
35.3 |
% |
50.1 |
% | |||
Less: Impact of cash and cash equivalents |
9.5 |
% |
— |
% | |||
Net Debt to Adjusted Capitalization Ratio |
25.8 |
% |
50.1 |
% |
SOURCE Cabot Oil & Gas Corporation
HOUSTON, April 4, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) will host its first quarter 2016 earnings conference call on Friday, April 29, 2016 at 9:30 a.m. Eastern Time. The Company plans to issue its financial and operating results prior to the market opening on the same day.
To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's website at www.cabotog.com.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 22, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today announced that it has priced an upsized public offering of 44,000,000 shares of its common stock at a price to the public of $20.00 per share. The Company has also granted the underwriters a 30 day option to purchase up to 6,600,000 additional shares of common stock. The offering is expected to close on February 26, 2016, subject to customary closing conditions. The Company expects to use the net proceeds from the offering for general corporate purposes, including repaying indebtedness under the Company's revolving credit facility, bolstering liquidity and funding a portion of the Company's capital program.
J.P. Morgan, BofA Merrill Lynch and Citigroup are acting as joint book-running managers for the offering. The offering is being made pursuant to an effective shelf registration statement filed with the Securities and Exchange Commission ("SEC"). The offering may be made only by means of a prospectus supplement and the accompanying prospectus, copies of which may be obtained by sending a request to (i) J.P. Morgan Securities LLC, c/o Broadridge Financial Solutions, 1155 Long Island Avenue, Edgewood, NY 11717, or by email at prospectus-eq_fi@jpmchase.com, (ii) BofA Merrill Lynch, 222 Broadway, New York, NY 10038, Attn: Prospectus Department, or by email at dg.prospectus_requests@baml.com, or (iii) Citigroup, c/o Broadridge Financial Solutions, 1155 Long Island Avenue, Edgewood, NY 11717; by email at prospectus@citi.com; or Toll-Free at (800) 831-9146.
Alternatively, copies of these documents may be obtained by visiting EDGAR on the SEC website at www.sec.gov.
This news release is for informational purposes only and shall not constitute an offer to sell or the solicitation of an offer to buy, nor shall there be any sale of these securities, in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States.
Statements in this news release that are not historical facts, including but not limited to those relating to the proposed public offering, the use of proceeds from the proposed public offering and other matters relating to the public offering, and other statements that are not historical facts are forward-looking statements that are based on current expectations. Although Cabot believes that its expectations are based on reasonable assumptions, it can give no assurance that these expectations will prove correct. Important factors that could cause actual results to differ materially from those in the forward-looking statements include results of operations, market conditions, capital needs and uses and other risks and uncertainties that are beyond Cabot's control, including those described in the prospectus and prospectus supplement, Cabot's Annual Report on Form 10-K for the year ended December 31, 2015 and its other filings with the SEC. Any forward-looking statement speaks only as of the date on which such statement is made and Cabot undertakes no obligation to correct or update forward-looking information.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 22, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today announced that it is commencing a registered public offering of 38,000,000 shares of its common stock. The Company also expects to grant the underwriters an option for 30 days to purchase up to 5,700,000 additional shares of common stock. The Company expects to use the net proceeds from the offering for general corporate purposes, including repaying indebtedness under the Company's revolving credit facility, bolstering liquidity and funding a portion of the Company's capital program.
J.P. Morgan and BofA Merrill Lynch are acting as joint book-running managers for the offering. The offering is being made pursuant to an effective shelf registration statement filed with the Securities and Exchange Commission ("SEC"). The offering may be made only by means of a prospectus supplement and the accompanying prospectus, copies of which may be obtained by sending a request to (i) J.P. Morgan Securities LLC, c/o Broadridge Financial Solutions, 1155 Long Island Avenue, Edgewood, NY 11717, or by email at prospectus-eq_fi@jpmchase.com, or (ii) BofA Merrill Lynch, 222 Broadway, New York, NY 10038, Attn: Prospectus Department, or by email at dg.prospectus_requests@baml.com.
Alternatively, copies of these documents may be obtained by visiting EDGAR on the SEC website at www.sec.gov.
This news release is for informational purposes only and shall not constitute an offer to sell or the solicitation of an offer to buy, nor shall there be any sale of these securities, in any state or jurisdiction in which such offer, solicitation or sale of these securities would be unlawful prior to registration or qualification under the securities laws of any such state or jurisdiction.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States.
Statements in this news release that are not historical facts, including but not limited to those relating to the proposed public offering, the use of proceeds from the proposed public offering and other matters relating to the public offering, and other statements that are not historical facts are forward-looking statements that are based on current expectations. Although Cabot believes that its expectations are based on reasonable assumptions, it can give no assurance that these expectations will prove correct. Important factors that could cause actual results to differ materially from those in the forward-looking statements include results of operations, market conditions, capital needs and uses and other risks and uncertainties that are beyond Cabot's control, including those described in the prospectus and prospectus supplement, Cabot's Annual Report on Form 10-K for the year ended December 31, 2015 and its other filings with the SEC. Any forward-looking statement speaks only as of the date on which such statement is made and Cabot undertakes no obligation to correct or update forward-looking information.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
HOUSTON, Feb. 2, 2016 /PRNewswire/ -- Cabot Oil & Gas Corporation (NYSE: COG) ("Cabot" or the "Company") today provided an operational update for the fourth quarter and full year 2015 and announced an updated 2016 operating plan and capital budget.
Fourth Quarter and Full Year 2015 Operational Update
Cabot expects production for the fourth quarter of 2015 to be approximately 1,642 million cubic feet equivalent (Mmcfe) per day, including approximately 1,552 million cubic feet (Mmcf) per day of natural gas and approximately 14,977 barrels (Bbl) per day of liquids (crude oil/condensate/natural gas liquids). Equivalent production for the quarter is expected to exceed the midpoint of the Company's guidance range of 1,626 Mmcfe per day. Based on the expected production volumes for the fourth quarter, the Company expects its total production growth for 2015 to be approximately 13 percent.
Natural gas price realizations, including the effect of hedges, are expected to be $1.94 per thousand cubic feet (Mcf) in the fourth quarter of 2015. Excluding the impact of hedges, natural gas price realizations for the quarter are expected to be $1.52 per Mcf, representing a $0.75 discount to NYMEX settlement prices and an improvement relative to the Company's fourth quarter guidance range of $0.90 to $1.00 below NYMEX settlement prices. Realized natural gas prices exceeded the Company's expectations due to an improvement in basis differentials throughout Appalachia during the quarter. Oil price realizations are expected to be $37.74 per Bbl.
Cabot expects to incur approximately $97 million in capital expenditures associated with activity during the fourth quarter of 2015. Based on this anticipated level of spending during the quarter, the Company expects to incur approximately $774 million in capital expenditures associated with activity during the full year of 2015, compared to the Company's 2015 capital program guidance of $850 million. The lower capital spending was a result of reduced activity levels in the fourth quarter, along with continued improvements in operating efficiencies and further reductions in service costs. Including the change in accrued capital costs relating to 2014 operating activity that was paid in 2015, total capital expenditures (including acquisitions) for 2015 are expected to be approximately $972 million. Contributions to equity method investments for 2015 are expected to be approximately $29 million.
Cabot expects to recognize a non-cash, after-tax impairment charge of approximately $73 million in the fourth quarter of 2015 primarily associated with legacy, non-core fields due to the significant decline in commodity prices.
2016 Operating Plan and Capital Budget Update
In response to the decline in both crude oil and natural gas prices since releasing its preliminary 2016 budget in October 2015, Cabot has reduced its 2016 capital budget to $325 million, which represents a reduction of 47 percent from the preliminary budget of $615 million and a reduction of 58 percent from the 2015 capital program of $774 million. Drilling, completion and facilities capital will account for approximately 92 percent of the capital budget, with approximately 70 percent allocated to the Marcellus Shale and approximately 30 percent allocated to the Eagle Ford Shale. The Company expects to drill approximately 30 net wells in 2016, including 25 net wells in the Marcellus Shale and 5 net wells in the Eagle Ford Shale. The Company anticipates completing approximately 55 net wells in 2016, including 40 net wells in the Marcellus Shale and 15 net wells in the Eagle Ford Shale. Cabot plans to reduce its rig count to one rig company-wide by mid-February 2016. As a result of the significant reduction in planned operating activity, the Company's 2016 production growth guidance range is being reduced at the top-end from 2 - 10 percent to 2 - 7 percent.
In addition to the $325 million capital budget associated with development activities, Cabot anticipates between $80 million and $150 million of contributions to its equity method investments in the Constitution and Atlantic Sunrise pipelines, which will ultimately be dependent on the regulatory approval process and the corresponding impact on the timing of construction activities.
Based on current market indications for commodity prices at the time of this press release, Cabot expects its natural gas price realizations before the impact of hedges to average $0.75 below NYMEX for the full year of 2016, an improvement relative to the preliminary guidance provided in October 2015 of $0.85 below NYMEX. For further disclosure on the Company's updated cost guidance for 2016, please see the current Guidance slide in the Investor Relations section of the Company's website.
"Consistent with our philosophy of disciplined capital investment through all commodity cycles, we have reduced our 2016 capital program in response to the lower commodity price environment and its anticipated impact on our operating cash flow for the year," said Dan O. Dinges, Chairman, President and Chief Executive Officer. "Our reduction in capital spending reflects our commitment to maintaining a strong balance sheet and highlights the capital efficiency of our asset base." Dinges added, "Given the productivity of our assets in the Marcellus Shale, we will be prepared to accelerate our production growth in a capital efficient manner when market conditions warrant, as we anticipate over 1.3 billion cubic feet (Bcf) per day of new firm transport capacity and firm sales by the third quarter of 2017 and an incremental 425 Mmcf per day by the third quarter of 2018."
2016 Derivative Position Update
The Company has approximately 52 Bcf of natural gas swaps for the period of April to October 2016 at a weighted average price of approximately $2.51 per Mcf.
Fourth Quarter and Full Year 2015 Conference Call
A conference call is scheduled for Friday, February 19, 2016, at 9:30 a.m. Eastern Time to discuss fourth quarter and full year 2015 financial and operating results. To access the live audio webcast, please visit the Investor Relations section of the Company's website at www.cabotog.com. A replay of the call will also be available on the Company's website. The latest financial guidance, including the Company's hedge positions, is also available in the Investor Relations section of the Company's website.
Cabot Oil & Gas Corporation, headquartered in Houston, Texas, is a leading independent natural gas producer with its entire resource base located in the continental United States. For additional information, visit the Company's homepage at www.cabotog.com.
The statements regarding future financial performance and results and the other statements which are not historical facts contained in this release are forward-looking statements that involve risks and uncertainties, including, but not limited to, market factors, the market price (including regional basis differentials) of natural gas and oil, results of future drilling and marketing activity, future production and costs, and other factors detailed in the Company's Securities and Exchange Commission filings.
FOR MORE INFORMATION CONTACT
Matt Kerin (281) 589-4642
SOURCE Cabot Oil & Gas Corporation
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