COST: 245 $MM
VOLUMES: 3.4 MBOE/d
ACRES: 24500 Acres
COST: 420 $MM
VOLUMES: 18.83 MBOE/d
ACRES: 34167
HOUSTON, Aug. 27, 2020 /PRNewswire/ -- EP Energy Corporation ("EP Energy" or the "Company") today announced that the United States Bankruptcy Court for the Southern District of Texas (the "Court") has confirmed the Company's Amended Plan of Reorganization (the "Amended Plan"). The Company expects to complete its financial restructuring process and emerge from Chapter 11 bankruptcy protection by October 1, 2020.
Upon emergence, EP Energy will reduce its debt by approximately $4.4 billion and receive $629 million in senior secured exit financing from the Company's existing revolving loan lenders. In total, the restructuring process will have eliminated approximately 90% of pre-petition funded debt and over 90% of pre-petition annual cash interest expense. Following completion of the process, EP Energy expects to have less than $500 million of debt and a new three-year reserve based loan credit facility.
President and Chief Executive Officer Russell Parker said, "We are pleased to have received court approval of our Amended Plan, which enables us to emerge from this process with a strong balance sheet and sustainable business model that is positioned for success throughout commodity cycles – including today's challenging operating environment and historically low oil prices. We expect to generate significant free cash flow on a go-forward basis which will provide valuable flexibility to create value for our stakeholders."
Mr. Parker continued, "I want to thank our dedicated employees for their commitment and unwavering focus to help us reach this important milestone in EP Energy's financial transformation. I also want to thank our banks, which have provided invaluable support to the Company with the Debtor-In-Possession and Exit Facility financings. On behalf of the EP Energy Board and management team, I also want to express my appreciation for the continued partnership and support of our vendors, lessors and royalty owners. We look forward to completing this process over the coming weeks and beginning a new, stronger chapter."
Additional Information
Additional resources for vendors, royalty owners, lessors and other stakeholders is available on EP Energy's restructuring website at www.epenergy.com/restructuring.html. Court filings and other documents related to the Chapter 11 process are available on a separate website administered by EP Energy's claims agent, Prime Clerk, at https://cases.primeclerk.com/EPEnergy. Information is also available by calling 877-502-9869 (toll-free in the U.S.) or +1-917-947-2373 (for calls originating outside the U.S.) or sending an email to EPEnergyinfo@primeclerk.com.
Weil, Gotshal & Manges LLP is serving as the Company's legal counsel, Evercore is serving as financial advisor and FTI Consulting, Inc. is serving as restructuring advisor.
About EP Energy Corporation
The Company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Forward Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. Such statements are subject to risks and uncertainties that could cause results to differ materially from the Company's expectations. While the Company makes these statements in good faith, neither the Company nor its management can guarantee that anticipated future results will be achieved. The Company assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by the Company, whether as a result of new information, future events, or otherwise. All forward-looking statements attributable to the Company or persons acting on the Company's behalf are expressly qualified in their entirety by the foregoing cautionary statements. All such statements speak only as of the date made, and, except as required by law, the Company undertakes no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events or otherwise.
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SOURCE EP Energy Corporation
HOUSTON, May 23, 2019 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) (the "Company") today confirmed that the New York Stock Exchange ("NYSE") has suspended trading in the Company's common stock, effective immediately, and has initiated proceeding to delist the common stock from the NYSE. The determination was based on "abnormally low" price levels of the Company's common stock pursuant to Section 802.01D of the NYSE Listed Company Manual.
The NYSE stated that it will apply to the Securities and Exchange Commission ("SEC") to delist the Company's common stock upon completion of all applicable procedures.
The Company expects that its common stock will begin to trade on OTC Pink markets beginning May 24, 2019 under the symbol "EPEG". The transition to the over-the-counter markets will not affect the Company's business operations. The Company will remain subject to the public reporting requirements of the SEC following the transfer.
About EP Energy
The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed. Whenever possible, these forward-looking statements are identified by words such as "expects," "believes," "anticipates" and similar phrases. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
Jordan.Strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, May 8, 2019 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today reported first quarter 2019 financial and operational results.
1Q'19 Results:
1Q'19 Operating and Financial Performance
Below is a summary of first quarter 2019 results compared to the first quarter 2018:
1Q'19 | 1Q'18 | 1Q'19 vs. 1Q'18 | |
Oil Production (MBbls/d) | 39.4 | 45.4 | - 13% |
Equivalent Production (MBoe/d) | 73.2 | 80.1 | - 9% |
Percent Oil (%) | 53.8 | 56.7 | - 5% |
LOE per Unit ($/Boe) | 5.55 | 5.48 | + 1% |
Lease Operating Expense ($MM) | 37 | 39 | - 5% |
G&A expense per Unit ($/Boe) | 3.16 | 2.58 | + 22% |
Adjusted G&A expense per Unit ($/Boe)1 | 2.50 | 2.31 | + 7% |
Net Income (Loss) ($MM) | (140) | 18 | - 878% |
Adjusted EBITDAX ($MM)1 | 148 | 189 | - 22% |
Oil and Gas Expenditures ($MM) | 154 | 456 | - 66% |
Adjusted Oil and Gas Expenditures (excl. acquisition capital ) ($MM)1 | 150 | 208 | - 28% |
Net completions (frac'd) | 10 | 35 | - 71% |
Change in DUC inventory from prior quarter | 17 | (5) | + 440 % |
1 See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
Financial Position and Liquidity
The company ended the quarter with $10 million in cash, $180 million borrowings outstanding on the RBL Facility, and $19 million in letters of credit, resulting in $440 million of available liquidity and $4.5 billion of net debt. The company repurchased $50 million in principal amount of its unsecured notes at a discount in the quarter. In April 2019, the banks reaffirmed the current RBL Facility borrowing base of $1.36 billion and commitments of $629 million.
Operations Update
For the first quarter 2019, average daily production was 73.2 MBoe/d, including 39.4 MBbls/d of oil. During the first quarter 2019, the company completed (frac'd) 17 gross wells (10 net) and incurred capital expenditures of $150 million, excluding acquisitions. The company had lower production in the first quarter 2019 compared to the first quarter 2018 due to lower net completions during the first quarter 2019 and fourth quarter 2018.
Northeastern Utah (NEU)
In the first quarter 2019, the company's assets in NEU produced 15.5 MBoe/d, including 10.0 MBbls/d of oil, a 10% and 14% decrease, respectively, from the first quarter 2018. EP Energy operated one drilling rig and completed (frac'd) four gross (one net) wells, of which two were vertical and two were horizontal, in the first quarter 2019. Total capital invested in NEU in the first quarter 2019 was $25 million excluding acquisition capital.
In the second quarter 2019, the company expects to average one drilling rig and complete and bring online three gross (three net) horizontal wells in late June in NEU.
Eagle Ford
EP Energy's assets in Eagle Ford produced 33.0 MBoe/d, including 22.2 MBbls/d of oil in the first quarter 2019, both an 8% decrease from the first quarter 2018. EP Energy averaged approximately three drilling rigs, invested $125 million excluding acquisition capital and completed (frac'd) 13 gross (nine net) wells in the first quarter 2019. The majority of these wells came online in March.
The company expects to average three drilling rigs and complete 13 gross wells (10 net) over the second quarter 2019, focusing on development in the southern and eastern portion of the La Salle acreage.
Permian
EP Energy's assets in the Permian basin produced 24.7 MBoe/d, including 7.2 MBbls/d of oil in the first quarter 2019, a 9% and 27% decrease, respectively, from the first quarter 2018. In the first quarter 2019, the company did not drill or complete any wells in the basin.
Hedge Program Update
EP Energy maintains a solid hedge program which provides continued commodity price protection. A summary of the company's current open hedge positions is listed below:
2019 | 2020 | |||||||||
Total Fixed Price Hedges | ||||||||||
Oil volumes (MMBbls)1 | 10.2 | 11.7 | ||||||||
Average ceiling price ($/Bbl) | $ | 66.41 | $ | 65.11 | ||||||
Average floor price ($/Bbl) | $ | 55.95 | $ | 55.90 | ||||||
Natural Gas volumes (TBtu) | 19.3 | — | ||||||||
Average price ($/MMBtu) | $ | 3.72 | $ | — | ||||||
Average floor price ($/MMBtu) | $ | 2.86 | $ | — | ||||||
Note: Positions are as of May 1, 2019 (Contract months: April 1, 2019 - Forward) | ||||||||||
1 The table includes WTI three-way collars of 9.1 MMBbls and 11.7 MMBbls in 2019 and 2020, respectively, and WTI collars of 1.1 MMBbls in 2019. |
2019 Second Quarter Outlook Provided
The table below summarizes the company's current operational and financial guidance for the second quarter 2019. The company plans to maintain the activity levels from the end of the first quarter through the second quarter 2019.
1Q'19 | 2Q'19 | ||||||
Production Volumes | |||||||
Oil production (MBbls/d) | 39.4 | 37 - 39 | |||||
Total production (MBoe/d) | 73.2 | 70 - 73 | |||||
Oil & Gas Expenditures ($ million)1 | $150 | $140 - $150 | |||||
Eagle Ford | $125 | ~70% | |||||
NEU | $25 | ~30% | |||||
Average Gross Drilling Rigs and | |||||||
Eagle Ford | 3 | 3 | |||||
NEU | 1 | 1 | |||||
Gross completions (frac'd) | 17 | 16 | |||||
Net Completions (frac'd) | 10 | 13 | |||||
Ending DUC inventory | 46 | 65 | |||||
Operating Costs | |||||||
Lease operating expense ($MM) | $37 | $36 - $40 | |||||
Lease operating expense ($/Boe) | $5.55 | $5.60 - $6.10 | |||||
Reported G&A expense ($/Boe) | $3.16 | $2.95 - $3.50 | |||||
Adjusted G&A expense ($/Boe)2,4 | $2.50 | $2.35 - $2.90 | |||||
Transportation ($/Boe) | $3.74 | $3.60 - $3.90 | |||||
Taxes, other than income ($/Boe)3 | $1.73 | $2.50 - $2.75 | |||||
DD&A ($/Boe) | $14.34 | $14.50 - $15.50 | |||||
1 Includes ~15% non-drill capital for general equipment, capitalized G&A and interest, enhanced facility projects, enhanced oil recovery projects, leasing and seismic, and excludes net acquisition costs and divestiture proceeds of ~$4 million in 1Q'19. | |||||||
2 Adjusted G&A represents G&A expense less approximately $0.60 - $0.60 per Boe of non-cash compensation expense in 2Q'19 Estimate. | |||||||
3 Severance taxes estimates are based on current WTI prices. | |||||||
4 See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on May 9, 2019, to discuss its first quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials relating to the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID#1090228) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through June 11, 2019 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID#10131317).
About EP Energy
The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
The following table provides the company's production results, average realized prices, results of operations and certain non-GAAP financial measures for the periods presented. See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms.
Quarter ended March 31, | |||||||
2019 | 2018 | ||||||
Oil Sales Volumes (MBbls/d) | |||||||
Eagle Ford | 22.2 | 24.0 | |||||
NEU | 10.0 | 11.6 | |||||
Permian | 7.2 | 9.8 | |||||
Total Oil Sales Volumes | 39.4 | 45.4 | |||||
Natural Gas Sales Volumes (MMcf/d) | |||||||
Eagle Ford | 33 | 36 | |||||
NEU | 33 | 34 | |||||
Permian | 58 | 56 | |||||
Total Natural Gas Sales Volumes | 124 | 126 | |||||
NGLs Sales Volumes (MBbls/d) | |||||||
Eagle Ford | 5.3 | 5.9 | |||||
NEU | — | — | |||||
Permian | 7.8 | 7.8 | |||||
Total NGLs Sales Volumes | 13.1 | 13.7 | |||||
Equivalent Sales Volumes (MBoe/d) | |||||||
Eagle Ford | 33.0 | 35.9 | |||||
NEU | 15.5 | 17.2 | |||||
Permian | 24.7 | 27.0 | |||||
Total Equivalent Sales Volumes | 73.2 | 80.1 | |||||
Net (loss) income ($ in millions) | (140) | 18 | |||||
Adjusted EBITDAX ($ in millions) | 148 | 189 | |||||
Basic and diluted net (loss) income per common share ($) | (0.56) | 0.07 | |||||
Adjusted EPS ($) | (0.15) | (0.07) | |||||
Capital Expenditures ($ in millions)(1) | 154 | 456 | |||||
Adjusted Capital Expenditures ($ in millions) | 150 | 208 | |||||
Total Operating Expenses ($/Boe) | 28.60 | 31.11 | |||||
Adjusted Cash Operating Costs ($/Boe) | 13.52 | 13.97 | |||||
Depreciation, depletion and amortization rate ($/Boe) | 14.34 | 16.69 | |||||
Average realized prices(2) | |||||||
Oil price on physical sales ($/Bbl) | 54.32 | 61.56 | |||||
Oil, including financial derivatives ($/Bbl)(3) | 56.01 | 58.86 | |||||
Natural gas price on physical sales ($/Mcf) | 1.58 | 1.94 | |||||
Natural gas, including financial derivatives ($/Mcf)(3) | 1.76 | 2.03 | |||||
NGLs price on physical sales ($/Bbl) | 15.64 | 20.93 | |||||
NGLs, including financial derivatives ($/Bbl)(3) | 15.64 | 20.91 | |||||
_________________________ | |||||||
(1) | The quarters ended March 31, 2019 and 2018 include $4 million and $248 million of acquisition capital, respectively. | ||||||
(2) | Oil and natural gas prices on physical sales reflect operating revenues for oil and natural gas reduced by oil and natural gas purchases associated with managing our physical sales. | ||||||
(3) | Prices per unit are calculated using total financial derivative cash settlements. |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF INCOME (In millions) (Unaudited) | |||||||
Quarter ended March 31, | |||||||
2019 | 2018 | ||||||
Operating revenues | |||||||
Oil | $ | 193 | $ | 252 | |||
Natural gas | 18 | 22 | |||||
NGLs | 18 | 26 | |||||
Financial derivatives | (95) | (14) | |||||
Total operating revenues | 134 | 286 | |||||
Operating expenses | |||||||
Transportation costs | 25 | 25 | |||||
Lease operating expense | 37 | 39 | |||||
General and administrative | 21 | 19 | |||||
Depreciation, depletion and amortization | 94 | 120 | |||||
Exploration and other expense | 1 | 1 | |||||
Taxes, other than income taxes | 11 | 20 | |||||
Total operating expenses | 189 | 224 | |||||
Operating (loss) income | (55) | 62 | |||||
Gain on extinguishment/modification of debt | 10 | 41 | |||||
Interest expense | (95) | (85) | |||||
(Loss) income before income taxes | (140) | 18 | |||||
Income tax expense | — | — | |||||
Net (loss) income | $ | (140) | $ | 18 |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED BALANCE SHEETS (In millions) (Unaudited) | |||||||
March 31, 2019 | December 31, 2018 | ||||||
ASSETS | |||||||
Current assets | $ | 234 | $ | 385 | |||
Property, plant and equipment, net(1) | 3,834 | 3,774 | |||||
Other non-current assets | 33 | 22 | |||||
Total assets | $ | 4,101 | $ | 4,181 | |||
LIABILITIES AND EQUITY | |||||||
Current liabilities | $ | 403 | $ | 440 | |||
Long-term debt, net of debt issue costs | 4,368 | 4,285 | |||||
Other non-current liabilities | 66 | 55 | |||||
Total stockholders' equity | (736) | (599) | |||||
Total liabilities and equity | $ | 4,101 | $ | 4,181 | |||
________________________ | |||||||
(1) | Balance is net of accumulated depreciation, depletion and amortization of $3,722 million and $3,651 million as of March 31, 2019 and December 31, 2018, respectively. |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (In millions) (Unaudited) | |||||||
Three months ended March 31, | |||||||
2019 | 2018 | ||||||
Net (loss) income | $ | (140) | $ | 18 | |||
Adjustments to reconcile net (loss) income to net cash provided | |||||||
Non-cash expenses | 92 | 84 | |||||
Asset and liability changes | 120 | (15) | |||||
Net cash provided by operating activities | 72 | 87 | |||||
Net cash used in investing activities | (128) | (229) | |||||
Net cash provided by financing activities | 39 | 117 | |||||
Change in cash, cash equivalents and restricted cash | (17) | (25) | |||||
Cash, cash equivalents and restricted cash - beginning of period | 27 | 45 | |||||
Cash, cash equivalents and restricted cash - end of period | $ | 10 | $ | 20 |
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment/modification of debt, other costs that affect comparability, including transition, severance and other costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net income (loss) per share to Adjusted EPS:
Quarter ended March 31, 2019 | |||||||||||||
Pre Tax | After Tax | Diluted EPS(1) | |||||||||||
($ in millions, except earnings per share amounts) | |||||||||||||
Net loss | $ | (140) | $ | (0.56) | |||||||||
Adjustments(2) | |||||||||||||
Impact of financial derivatives(3) | $ | 103 | $ | 80 | $ | 0.32 | |||||||
Transition, severance and other costs | 1 | — | — | ||||||||||
Gain on extinguishment of debt | (10) | (8) | (0.03) | ||||||||||
Valuation allowance on deferred tax assets | 31 | 0.12 | |||||||||||
Total adjustments | $ | 94 | $ | 103 | $ | 0.41 | |||||||
Adjusted EPS | $ | (0.15) | |||||||||||
Diluted weighted average shares | 249 | ||||||||||||
Quarter ended March 31, 2018 | |||||||||||||
Pre Tax | After Tax | Diluted EPS(1) | |||||||||||
($ in millions, except earnings per share amounts) | |||||||||||||
Net income | $ | 18 | $ | 0.07 | |||||||||
Adjustments(2) | |||||||||||||
Impact of financial derivatives(3) | $ | 4 | $ | 3 | $ | 0.01 | |||||||
Gain on extinguishment of debt | (41) | (32) | (0.13) | ||||||||||
Valuation allowance on deferred tax assets | (5) | (0.02) | |||||||||||
Total adjustments | $ | (37) | $ | (34) | $ | (0.14) | |||||||
Adjusted EPS | $ | (0.07) | |||||||||||
Diluted weighted average shares | 247 | ||||||||||||
_________________________ | |||||||||||||
(1) | Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | ||||||||||||
(2) | All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. | ||||||||||||
(3) | Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, and gains and losses on extinguishment/modification of debt.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter ended March 31, | ||||||||
2019 | 2018 | |||||||
($ in millions) | ||||||||
Net (loss) income | $ | (140) | $ | 18 | ||||
Income tax expense | — | — | ||||||
Interest expense, net of capitalized interest | 95 | 85 | ||||||
Depreciation, depletion and amortization | 94 | 120 | ||||||
Exploration expense | 1 | 1 | ||||||
EBITDAX | 50 | 224 | ||||||
Mark-to-market on financial derivatives(1) | 95 | 14 | ||||||
Cash settlements and cash premiums on financial | 8 | (10) | ||||||
Non-cash portion of compensation expense(3) | 4 | 2 | ||||||
Transition, severance and other costs(4) | 1 | — | ||||||
Gain on extinguishment/modification of debt | (10) | (41) | ||||||
Adjusted EBITDAX | $ | 148 | $ | 189 |
_________________________ | ||||||||||
(1) | Represents the income statement impact of financial derivatives. | |||||||||
(2) | Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | |||||||||
(3) | Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. | |||||||||
(4) | Reflects transition and severance costs related to workforce reductions. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, severance and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended March 31, | ||||||||||||||||
2019 | 2018 | |||||||||||||||
Total | Per-Unit(1) | Total | Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Transportation costs | 25 | 3.74 | 25 | 3.43 | ||||||||||||
Lease operating expense | 37 | 5.55 | 39 | 5.48 | ||||||||||||
General and administrative | 21 | 3.16 | 19 | 2.58 | ||||||||||||
Depreciation, depletion and amortization | 94 | 14.34 | 120 | 16.69 | ||||||||||||
Exploration and other expense | 1 | 0.08 | 1 | 0.18 | ||||||||||||
Taxes, other than income taxes | 11 | 1.73 | 20 | 2.75 | ||||||||||||
Total operating expenses | $ | 189 | $ | 28.60 | $ | 224 | $ | 31.11 | ||||||||
Adjustments: | ||||||||||||||||
Depreciation, depletion and amortization | $ | (94) | $ | (14.34) | $ | (120) | $ | (16.69) | ||||||||
Exploration expense | (1) | (0.08) | (1) | (0.18) | ||||||||||||
Non-cash portion of compensation expense(2) | (4) | (0.57) | (2) | (0.27) | ||||||||||||
Transition, severance and other costs(2) | (1) | (0.09) | — | — | ||||||||||||
Adjusted cash operating costs and per-unit adjusted | $ | 89 | $ | 13.52 | $ | 101 | $ | 13.97 | ||||||||
Total consolidated equivalent volumes (MBoe) | 6,588 | 7,208 | ||||||||||||||
_________________________ | ||||||||||||||||
(1) Per unit costs are based on actual total amounts rather than the rounded totals presented. | ||||||||||||||||
(2) Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans and transition, severance and other costs. Adjusted cash general and administrative expenses are defined as adjusted general and administrative expenses including capitalized labor.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense and non-GAAP adjusted cash general and administrative expense:
Actuals | |||||||||||||||||||||||
Quarter ended March 31, | 2Q'19 Estimate | ||||||||||||||||||||||
2019 | 2018 | Low | High | ||||||||||||||||||||
Total | ($/Boe)1 | Total | ($/Boe)1 | ($/Boe) | ($/Boe) | ||||||||||||||||||
($ in millions, except per Boe costs) | |||||||||||||||||||||||
GAAP general and administrative expense | $ | 21 | $ | 3.16 | $ | 19 | $ | 2.58 | $ | 2.95 | $ | 3.50 | |||||||||||
Less non-cash compensation expense | 4 | 0.57 | 2 | 0.27 | 0.60 | 0.60 | |||||||||||||||||
Less transition, severance and other costs | 1 | 0.09 | — | — | — | — | |||||||||||||||||
Adjusted general and administrative expense | $ | 16 | $ | 2.50 | $ | 17 | $ | 2.31 | $ | 2.35 | $ | 2.90 | |||||||||||
Capitalized labor | 3 | 0.39 | 4 | 0.59 | |||||||||||||||||||
Adjusted cash general and administrative expense | $ | 19 | $ | 2.89 | $ | 21 | $ | 2.90 | |||||||||||||||
_________________________ | |||||||||||||||||||||||
(1) Per unit costs are based on actual total amounts rather than the rounded totals presented. |
Net Debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents. At March 31, 2019, the Company's net debt was approximately $4.5 billion (total debt $4,468 million less cash and cash equivalents of approximately $10 million).
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted Cash Operating Costs ($ and per unit) are used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and related per unit measures as well as Adjusted Oil and Gas Expenditures are used by management and investors as additional information as noted above. Net Debt is used by management for analysis of the company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative expense and Adjusted Cash General and Administrative expense should not be used as an alternative to GAAP general and administrative expense. Adjusted Oil and Gas Expenditures should not be used as an alternative to oil and gas capital expenditures or other measures of liquidity presented in accordance with GAAP. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and potential for sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the ability to develop proved undeveloped reserves; the future level of operating and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to generate sufficient cash flow to meet its debt obligations and commitments; the possibility that the company may not be able to continue as a going concern beginning in May 2020 if it is not successful in obtaining the necessary additional liquidity and/or if commodity prices do not appreciably increase; the company's limited ability to borrow under existing debt agreements to fund its operations; the company's ability to generate sufficient cash flow to meet its debt obligations and commitments; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies, including potential downgrades; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, March 14, 2019 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today reported 2018 financial and operational results for the company.
2018 Key Results:
2018 Operating and Financial Performance
Below is a summary of fourth quarter 2018 results compared to the fourth quarter 2017 and full year 2018 results compared to 2017:
4Q'17 | 4Q'18 | 4Q'18 | 2017 | 2018 | 2018 vs 2017 | ||
Oil Production (MBbls/d) | 43.6 | 44.3 | + 2% | 46.1 | 45.8 | - 1% | |
Equivalent Production (MBoe/d) | 80.6 | 79.5 | - 1% | 82.3 | 80.7 | - 2% | |
Percent Oil (%) | 54 | 56 | + 3% | 56 | 57 | + 1% | |
LOE per Unit ($/Boe) | 5.60 | 4.84 | - 14% | 5.42 | 5.35 | - 1% | |
Adjusted LOE per Unit ($/Boe)1,2 | 5.60 | 4.83 | - 14% | 5.42 | 5.28 | - 3% | |
Lease Operating Expense ($MM) | 42 | 35 | - 15% | 163 | 158 | - 4% | |
Adjusted Lease Operating Expense ($MM)1,2 | 42 | 35 | - 16% | 163 | 156 | - 4% | |
G&A expense per Unit ($/Boe)3 | 1.35 | 2.86 | +112% | 2.69 | 3.03 | + 13% | |
Adjusted G&A expense per Unit ($/Boe)1 | 2.05 | 1.99 | - 3% | 2.62 | 2.24 | - 15% | |
Net (Loss) ($MM) | (72) | (919) | - 1,176% | (194) | (1,003) | - 417% | |
Hedge Settlements ($MM) | 7 | 9 | -29% | 93 | (25) | - 215% | |
Adjusted EBITDAX ($MM)1 | 181 | 195 | + 8% | 691 | 813 | + 18% | |
Oil and Gas Expenditures ($MM) | 145 | 107 | - 26% | 587 | 984 | + 68% | |
Adjusted Oil and Gas Expenditures (excl. Acquisitions and Other ) ($MM)1 | 145 | 99 | - 32% | 558 | 644 | + 15% |
1 | See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
2 | Does not include less than $1 million and approximately $2 million or $0.01 per Boe and $0.07 per Boe for the quarter and year ended December 31, 2018 of adjustments under a joint venture agreement. |
3 | Includes approximately $33 million reduction from LTI forfeitures for the quarter and year ended December 31, 2017. |
Fourth Quarter 2018
For the quarter ended December 31, 2018, EP Energy reported a $3.70 diluted net loss per share and $0.13 adjusted loss per share. The reported net loss for the fourth quarter of 2018 was $919 million, versus a $72 million net loss in the same 2017 period, which is primarily due to non-cash impairment charges. Adjusted EBITDAX for the fourth quarter 2018 was $195 million, up from $181 million in the fourth quarter of 2017, due to higher oil volumes, lower cash costs and higher realized pricing on oil physical sales.
The company ended the year with fourth quarter operating expenses of $1,328 million, up from $217 million in the fourth quarter of 2017 due to non-cash impairment charges in 2018. Adjusted cash operating costs were $89 million for the fourth quarter 2018, down from $101 million in the same 2017 period. Adjusted cash operating costs were $12.16 per barrel of oil equivalent (Boe) for the fourth quarter 2018, down from $13.65 per Boe in the same 2017 period mainly due to lower lease operating costs.
Capital expenditures in the fourth quarter 2018 were $107 million, down from $145 million in the same period 2017, primarily due to decreased drilling activity in the Permian in 2018. Capital expenditures for each area during the fourth quarter of 2018 were approximately $83 million in the Eagle Ford, $22 million in Northeastern Utah, and $2 million in Permian. In the fourth quarter 2018, the company completed 27 gross wells, 22 of which were in the Eagle Ford and 5 in NEU.
Full Year 2018
For the year ended December 31, 2018, EP Energy reported a $4.05 diluted net loss per share and $0.25 adjusted loss per share. Reported net loss was $1,003 million for the year 2018, compared to a $194 million net loss in the same 2017 period, which includes approximately $1,103 million asset impairment charges related to the Permian in 2018. Adjusted EBITDAX for the year 2018 was $813 million, up from $691 million in 2017 due primarily to lower lease operating expenses, lower adjusted general and administrative expenses, and higher realized pricing on oil and NGL volumes in 2018.
Total operating expenses for the year ended December 31, 2018 were $2,039 million, up from $927 million in the same 2017 period. The difference was driven by non-cash impairment charges of $1,103 million related to the company's Permian assets in 2018. Adjusted cash operating costs were $406 million for the year 2018, down from $427 million in the same 2017 period. Adjusted cash operating costs per unit were $13.77 per Boe for the year 2018, down from $14.23 per Boe in the same 2017 period primarily due to lower lease operating expenses, lower transportation costs, and lower adjusted general and administrative expense in 2018.
Adjusted oil and gas expenditures in 2018 were $644 million, up from $558 million in the same period 2017. In 2018, the company spent $425 million in Eagle Ford (excluding $315 million of acquisition capital), $99 million in the Permian (excluding $23 million in capital adjustments under a joint venture agreement) and $120 million in Northeastern Utah (excluding $2 million in acquisition capital). In 2018, the company completed 136 gross wells, which was approximately 13 less than EP Energy completed in 2017. In 2018, the company completed 85 wells in the Eagle Ford, 24 wells in the Permian, and 27 wells in Northeastern Utah. In addition the company ended the year with 29 DUC's.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Financial Position and Liquidity
At December 31, 2018, EP Energy's balance sheet included $4.4 billion of total debt and approximately $27 million of cash and cash equivalents. As of December 31, 2018, the company had $537 million of total liquidity. The company also repurchased $84 million of unsecured notes during the year at a discount. In 2019 the company repurchased an additional $50 million of its unsecured notes at a discount as of February 28, 2019.
Operations Update
For the year ended December 31, 2018, average daily production was 80.7 MBoe/d, including 45.8 MBbls/d of oil. Fourth quarter 2018 average daily production was 79.5 MBoe/d, including 44.3 MBbls/d of oil. During the fourth quarter of 2018, the company completed (frac'd) 27 gross wells (13 net). The decrease in the fourth quarter of 2018 production is due to lower net completions in the second half of 2018.
Northeastern Utah (NEU)
EP Energy's assets in Northeastern Utah averaged approximately 17.0 MBoe/d during the fourth quarter of 2018, which included 11.5 MBbls/d of oil while also completing five gross wells (2 net). The company's focus in 2018 in NEU was horizontal well development and recompletion activity. During 2018 EP Energy successfully completed the company's first ever horizontal wells in the basin. In the first quarter of 2019, the company expects to average one operated rig focused on horizontal drilling while bringing four gross wells (two net) to sales.
Eagle Ford
EP Energy's assets in Eagle Ford averaged approximately 37.3 MBoe/d during the fourth quarter of 2018, which included 24.7 MBbls/d of oil while also completing 22 gross wells (11 net). During 2018 the company expanded its footprint by almost 30% in the Eagle Ford through A&D activity. The company expects to average three operated rigs and one completion crew while bringing approximately 13 gross wells (8 net ) to sales in the first quarter of 2019.
Permian
EP Energy's assets in the Permian basin averaged approximately 25.2 MBoe/d per day during the fourth quarter of 2018, which included 8.1 MBbls/d of oil. The company will not have any rigs or completion crews in the first quarter of 2019 in the Permian.
Hedge Program Update
In 2018, EP Energy realized negative $25 million from settlements on financial derivatives. At year-end 2018, the mark-to-market value of the company's hedge positions was approximately $114 million.
A summary of the company's 2019 and 2020 hedge positions is listed below:
2019 | 2020 | ||||||
Total Fixed Price Hedges | |||||||
Oil volumes (MMBbls) | 13.7 | 11.7 | |||||
Average ceiling price ($/Bbl) | $ | 66.41 | $ | 65.11 | |||
Average floor price ($/Bbl) | $ | 55.93 | $ | 55.90 | |||
Natural gas volumes (TBtu) | 25.6 | — | |||||
Average ceiling prices ($/MMBtu) | $ | 3.72 | $ | — | |||
Average floor prices ($/MMBtu) | $ | 2.86 | $ | — |
Note: Positions are as of March 13, 2019 (Contract months: January 2019 - Forward) |
The table includes WTI three-way collars of 12.1 MMBbls and 11.7 MMBbls in 2019 and 2020, respectively, and WTI collars of 1.6 MMBbls in 2019. |
2018 Proved Reserves
Ryder Scott, who was engaged in prior years to solely audit year-end reserves estimates, prepared the reserves estimates on EP Energy's behalf in 2018. EP Energy's proved oil and natural gas reserves were 325 MMBoe as of December 31, 2018, a 17 percent decrease compared to proved reserves at December 31, 2017 of 392 MMBoe. Our PUD reserves at December 31, 2018 reflect the effects of adjusting our PUD bookings methodology from a five-year to a three-year timeframe as a result of the current economic price environment, a lower projected capital budget in 2019, and our available liquidity and access to the capital markets. Our December 31, 2018 PUD reserves are 64 MMBoe lower as a result of this change. Proved developed reserves increased ten percent from 205 MMBoe in 2017 to 234 MMBoe in 2018. In 2018, total proved reserves were 72 percent proved developed and 70 percent liquids.
The SEC first-day-of-the-month 12-month average prices for reserves as of December 31, 2018 were $65.56 per Bbl for oil and $3.10 per MMBtu for natural gas, up from $51.34 per Bbl for oil and $2.98 per MMBtu for natural gas in the prior 12-month period.
First Quarter 2019 Outlook
Given the uncertainty of commodity prices, EP Energy has elected to provide quarterly guidance updates. Production in first quarter 2019 is impacted by reduced net completion count over 4Q'18 and 1Q'19. First quarter 2019 capital expenditures is impacted by the build in DUC inventory.
The company has provided production and capital guidance for the first quarter of 2019 below:
1Q'19 | ||
Oil production (MBbls/d) | 38 - 39 | |
Total production (MBoe/d) | 72 - 73 | |
Oil & Gas Expenditures ($ million) | $160 - $170 | |
Eagle Ford | ~85% | |
Permian | ~0% | |
NEU | ~15% | |
Average gross drilling rigs | ||
Eagle Ford | 3 | |
Permian | — | |
NEU | 1 | |
Gross completions (based on fracture stimulated or frac'd) | ~17 | |
Ending drilled but uncompleted inventory | ~45 | |
Operating Costs | ||
Lease operating expense ($MM) | $38 - $41 | |
Lease operating expense ($/Boe) | $6.00 - $6.50 | |
G&A expense ($/Boe) | $2.75 - $3.15 | |
Adjusted G&A expense ($/Boe)1 | $2.20 - $2.60 | |
Transportation and commodity purchases ($/Boe) | $3.75 - $4.05 | |
Taxes, other than income ($/Boe)2 | $1.80 - $1.95 | |
DD&A ($/Boe) | $14.50 - $15.50 |
1 | Adjusted G&A represents G&A expense less approximately $0.55 - $0.55 per Boe of non-cash compensation expense. |
2 | Severance taxes are based on $55/Bbl WTI. |
Webcast Information
EP Energy has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on March 15, to discuss its fourth quarter and full year financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 4069531) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through April 15, 2019 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10129100).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
The following table provides the company's production results, average realized prices, results of operations and certain non-GAAP financial measures for the periods presented. See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms.
Quarter ended December 31, | Year ended December 31, | ||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||
Oil Sales Volumes (MBbls/d) | |||||||||||
Eagle Ford | 24.7 | 19.4 | 25.0 | 22.4 | |||||||
NEU | 11.5 | 12.2 | 11.7 | 12.3 | |||||||
Permian | 8.1 | 12.0 | 9.1 | 11.4 | |||||||
Total Oil Sales Volumes | 44.3 | 43.6 | 45.8 | 46.1 | |||||||
Natural Gas Sales Volumes (MMcf/d) | |||||||||||
Eagle Ford | 36 | 32 | 36 | 39 | |||||||
NEU | 33 | 34 | 32 | 33 | |||||||
Permian | 53 | 64 | 55 | 55 | |||||||
Total Natural Gas Sales Volumes | 122 | 130 | 123 | 127 | |||||||
NGLs Sales Volumes (MBbls/d) | |||||||||||
Eagle Ford | 6.6 | 5.9 | 6.1 | 6.8 | |||||||
NEU | — | — | — | — | |||||||
Permian | 8.3 | 9.4 | 8.2 | 8.2 | |||||||
Total NGLs Sales Volumes | 14.9 | 15.3 | 14.3 | 15.0 | |||||||
Equivalent Sales Volumes (MBoe/d) | |||||||||||
Eagle Ford | 37.3 | 30.6 | 37.1 | 35.7 | |||||||
NEU | 17.0 | 17.9 | 17.1 | 17.9 | |||||||
Permian | 25.2 | 32.1 | 26.5 | 28.7 | |||||||
Total Equivalent Sales Volumes | 79.5 | 80.6 | 80.7 | 82.3 | |||||||
Net loss ($ in millions) | (919) | (72) | (1,003) | (194) | |||||||
Adjusted EBITDAX ($ in millions) | 195 | 181 | 813 | 691 | |||||||
Basic and diluted net loss per common share ($) | (3.70) | (0.29) | (4.05) | (0.79) | |||||||
Adjusted EPS ($) | (0.13) | (0.07) | (0.25) | (0.39) | |||||||
Oil and Gas Expenditures ($ in millions)(1) | 107 | 145 | 984 | 587 | |||||||
Adjusted Oil and Gas Expenditures ($ in millions) | 99 | 145 | 644 | 558 | |||||||
Total Operating Expenses ($/Boe) | 181.47 | 29.16 | 69.25 | 30.86 | |||||||
Adjusted Cash Operating Costs ($/Boe) | 12.16 | 13.65 | 13.77 | 14.23 | |||||||
Depreciation, depletion and amortization rate ($/Boe) | 17.90 | 16.01 | 17.23 | 16.22 | |||||||
Average realized prices(2) | |||||||||||
Oil price on physical sales ($/Bbl) | 55.31 | 54.13 | 62.34 | 48.23 | |||||||
Oil, including financial derivatives ($/Bbl)(3) | 56.71 | 55.70 | 60.37 | 53.50 | |||||||
Natural gas price on physical sales ($/Mcf) | 1.76 | 2.14 | 1.66 | 2.32 | |||||||
Natural gas, including financial derivatives ($/Mcf)(3) | 2.16 | 2.44 | 1.96 | 2.47 | |||||||
NGLs price on physical sales ($/Bbl) | 20.29 | 22.72 | 22.88 | 18.87 | |||||||
NGLs, including financial derivatives ($Bbl)(3) | 19.51 | 20.98 | 21.79 | 18.46 |
______________________________________________ | |
(1) | The quarter and year ended December 31, 2018 includes $8 million and $340 million, respectively, of acquisition capital and capital adjustments under a joint venture agreement. The year ended December 31, 2017 includes $29 million of acquisition capital. |
(2) | Oil and natural gas prices on physical sales reflect operating revenues for oil and natural gas reduced by oil and natural gas purchases associated with managing our physical sales. |
(3) | Prices per unit are calculated using total financial derivative cash settlements. |
EP ENERGY CORPORATION | |||||||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF INCOME | |||||||||||||||
(In millions) | |||||||||||||||
(Unaudited) | |||||||||||||||
Quarter ended December 31, | Year ended December 31, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
Operating revenues | |||||||||||||||
Oil | $ | 225 | $ | 217 | $ | 1,045 | $ | 812 | |||||||
Natural gas | 20 | 26 | 75 | 110 | |||||||||||
NGLs | 28 | 32 | 120 | 103 | |||||||||||
Financial derivatives | 206 | (51) | 84 | 41 | |||||||||||
Total operating revenues | 479 | 224 | 1,324 | 1,066 | |||||||||||
Operating expenses | |||||||||||||||
Oil and natural gas purchases | — | — | 3 | 2 | |||||||||||
Transportation costs | 24 | 29 | 100 | 115 | |||||||||||
Lease operating expense | 35 | 42 | 158 | 163 | |||||||||||
General and administrative | 21 | 10 | 89 | 81 | |||||||||||
Depreciation, depletion and amortization | 131 | 119 | 507 | 487 | |||||||||||
Gain on sale of assets | (2) | — | (3) | — | |||||||||||
Impairment charges | 1,103 | — | 1,103 | 2 | |||||||||||
Exploration and other expense | 2 | 2 | 5 | 12 | |||||||||||
Taxes, other than income taxes | 14 | 15 | 77 | 65 | |||||||||||
Total operating expenses | 1,328 | 217 | 2,039 | 927 | |||||||||||
Operating (loss) income | (849) | 7 | (715) | 139 | |||||||||||
Other income | 2 | — | 4 | — | |||||||||||
Gain (loss) on extinguishment/modification of debt | 25 | — | 73 | (16) | |||||||||||
Interest expense | (97) | (81) | (365) | (326) | |||||||||||
Loss before income taxes | (919) | (74) | (1,003) | (203) | |||||||||||
Income tax benefit | — | 2 | — | 9 | |||||||||||
Net loss | $ | (919) | $ | (72) | $ | (1,003) | $ | (194) |
EP ENERGY CORPORATION | |||||||
CONDENSED CONSOLIDATED BALANCE SHEETS | |||||||
(In millions) | |||||||
(Unaudited) | |||||||
December 31, 2018 | December 31, 2017 | ||||||
ASSETS | |||||||
Current assets(1) | $ | 385 | $ | 466 | |||
Property, plant and equipment, net(2) | 3,774 | 4,422 | |||||
Other non-current assets | 22 | 12 | |||||
Total assets | $ | 4,181 | $ | 4,900 | |||
LIABILITIES AND EQUITY | |||||||
Current liabilities | $ | 440 | $ | 448 | |||
Long-term debt, net of debt issue costs | 4,285 | 4,022 | |||||
Other non-current liabilities | 4,340 | 4,060 | |||||
Total stockholders' equity | (599) | 392 | |||||
Total liabilities and equity | $ | 4,181 | $ | 4,900 |
_____________________________________________ | |
(1) | Balance as of December 31, 2017 includes $172 million of assets held for sale. |
(2) | Balance is net of accumulated depreciation, depletion and amortization of $3,651 million and $3,179 million as of December 31, 2018 and December 31, 2017, respectively. |
EP ENERGY CORPORATION | |||||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS | |||||||
(In millions) | |||||||
(Unaudited) | |||||||
Year ended December 31, | |||||||
2018 | 2017 | ||||||
Net loss | $ | (1,003) | $ | (194) | |||
Adjustments to reconcile net loss to net cash provided by operating activities | |||||||
Non-cash expenses | 1,564 | 505 | |||||
Asset and liability changes | (139) | 64 | |||||
Net cash provided by operating activities | 422 | 375 | |||||
Net cash used in investing activities | (790) | (577) | |||||
Net cash provided by financing activities | 350 | 227 | |||||
Change in cash, cash equivalents and restricted cash | (18) | 25 | |||||
Cash, cash equivalents and restricted cash - beginning of period | 45 | 20 | |||||
Cash, cash equivalents and restricted cash - end of period | $ | 27 | $ | 45 |
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment/modification of debt, gains and/or losses on sale of assets, impairment charges, other costs that affect comparability, including transition, severance and other costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net income (loss) per share to Adjusted EPS:
Quarter ended December 31, 2018 | |||||||||||
Pre-Tax | After-Tax | Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss | $ | (919) | $ | (3.70) | |||||||
Adjustments(2) | |||||||||||
Impact of financial derivatives(3) | $ | (197) | $ | (153) | $ | (0.62) | |||||
Transition, severance and other costs | 2 | 2 | $ | 0.01 | |||||||
Gain on extinguishment/modification of debt | (25) | (19) | $ | 0.01 | |||||||
Gain on sale of assets | (2) | (2) | (0.01) | ||||||||
Impairment charges | 1,103 | 859 | 3.46 | ||||||||
Valuation allowance on deferred tax assets | 200 | 0.81 | |||||||||
Total adjustments | $ | 881 | $ | 887 | $ | 3.57 | |||||
Adjusted EPS | $ | (0.13) | |||||||||
Diluted weighted average shares | 249 | ||||||||||
Year ended December 31, 2018 | |||||||||||
Pre-Tax | After-Tax | Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss | $ | (1,003) | $ | (4.05) | |||||||
Adjustments(2) | |||||||||||
Impact of financial derivatives(3) | $ | (109) | $ | (85) | $ | (0.34) | |||||
Transition, severance and other costs | 9 | 7 | 0.03 | ||||||||
Gain on extinguishment/modification of debt | (73) | (57) | (0.23) | ||||||||
Gain on sale of assets | (2) | (2) | (0.01) | ||||||||
Impairment charges | 1,103 | 859 | 3.47 | ||||||||
Valuation allowance on deferred tax assets | 218 | $ | 0.88 | ||||||||
Total adjustments | $ | 928 | $ | 940 | $ | 3.80 | |||||
Adjusted EPS | $ | (0.25) | |||||||||
Diluted weighted average shares | 248 |
___________________________________________________ | |
(1) | Diluted per share amounts are based on actual amounts rather than the rounded totals presented. |
(2) | All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(3) | Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, fees paid to Sponsors, gains and losses on extinguishment/modification of debt, gains and/or losses on sale of assets and impairment charges.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter ended December 31, | Year ended December 31, | ||||||||||||||
2018 | 2017 | 2018 | 2017 | ||||||||||||
($ in millions, except equivalent volumes and per unit) | |||||||||||||||
Net loss | $ | (919) | $ | (72) | $ | (1,003) | $ | (194) | |||||||
Income tax benefit | — | (2) | — | (9) | |||||||||||
Interest expense, net of capitalized interest | 97 | 81 | 365 | 326 | |||||||||||
Depreciation, depletion and amortization | 131 | 119 | 507 | 487 | |||||||||||
Exploration expense | 1 | 2 | 4 | 9 | |||||||||||
EBITDAX | (690) | 128 | (127) | 619 | |||||||||||
Mark-to-market on financial derivatives(1) | (206) | 51 | (84) | (41) | |||||||||||
Cash settlements and cash premiums on financial derivatives(2) | 9 | 7 | (25) | 93 | |||||||||||
Non-cash portion of compensation expense(3) | 4 | (29) | 13 | (22) | |||||||||||
Transition, severance and other costs(4) | 2 | 19 | 9 | 19 | |||||||||||
Fees paid to Sponsors(5) | — | 5 | — | 5 | |||||||||||
Gain on sale of assets | (2) | — | (3) | — | |||||||||||
(Gain) loss on extinguishment/modification of debt | (25) | — | (73) | 16 | |||||||||||
Impairment charges | 1,103 | — | 1,103 | 2 | |||||||||||
Adjusted EBITDAX | $ | 195 | $ | 181 | $ | 813 | $ | 691 |
_____________________________________________________ | |
(1) | Represents the income statement impact of financial derivatives. |
(2) | Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(3) | Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. |
(4) | Reflects transition and severance costs related to workforce reductions. |
(5) | Represents fees paid in connection with the release of members of the new leadership team from a portfolio company of funds managed by Apollo Global Management LLC and payment of certain legal expenses. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains/losses on sale of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, severance and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to our existing assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter Ended December 31, | |||||||||||||||
2018 | 2017 | ||||||||||||||
Total | Per Unit | Total | Per Unit | ||||||||||||
Oil and natural gas purchases | $ | — | $ | — | $ | — | $ | — | |||||||
Transportation costs | 24 | 3.32 | 29 | 3.92 | |||||||||||
Lease operating expense | 35 | 4.84 | 42 | 5.60 | |||||||||||
General and administrative | 21 | 2.86 | 10 | 1.35 | |||||||||||
Depreciation, depletion and amortization | 131 | 17.90 | 119 | 16.01 | |||||||||||
Gain on sale of assets | (2) | (0.31) | — | — | |||||||||||
Impairment charges | 1,103 | 150.70 | — | — | |||||||||||
Exploration and other expense | 2 | 0.29 | 2 | 0.20 | |||||||||||
Taxes, other than income taxes | 14 | 1.87 | 15 | 2.08 | |||||||||||
Total operating expenses | $ | 1,328 | $ | 181.47 | $ | 217 | $ | 29.16 | |||||||
Adjustments: | |||||||||||||||
Depreciation, depletion and amortization | $ | (131) | $ | (17.90) | $ | (119) | $ | (16.01) | |||||||
Impairment charges | (1,103) | (150.70) | — | — | |||||||||||
Exploration expense | (1) | (0.15) | (2) | (0.20) | |||||||||||
Gain on sale of assets | 2 | 0.31 | — | — | |||||||||||
Non-cash portion of compensation expense(2) | (4) | (0.56) | 29 | 3.95 | |||||||||||
Transition, severance and other costs(2) | (2) | (0.31) | (19) | (2.56) | |||||||||||
Fees paid to Sponsors(2) | — | — | (5) | (0.18) | |||||||||||
Adjusted cash operating costs and per unit adjusted cash costs | $ | 89 | $ | 12.16 | $ | 101 | $ | 13.65 | |||||||
Total consolidated equivalent volumes (MBoe) | 7,318 | 7,412 | |||||||||||||
Year Ended December 31, | |||||||||||||||
2018 | 2017 | ||||||||||||||
Total | Per-Unit | Total | Per-Unit | ||||||||||||
Oil and natural gas purchases | $ | 3 | $ | 0.10 | $ | 2 | $ | 0.07 | |||||||
Transportation costs | 100 | 3.41 | 115 | 3.83 | |||||||||||
Lease operating expense | 158 | 5.35 | 163 | 5.42 | |||||||||||
General and administrative | 89 | 3.03 | 81 | 2.69 | |||||||||||
Depreciation, depletion and amortization | 507 | 17.23 | 487 | 16.22 | |||||||||||
Gain on sale of assets | (3) | (0.13) | — | — | |||||||||||
Impairment charges | 1,103 | 37.47 | 2 | 0.04 | |||||||||||
Exploration and other expense | 5 | 0.18 | 12 | 0.40 | |||||||||||
Taxes, other than income taxes | 77 | 2.61 | 65 | 2.19 | |||||||||||
Total operating expenses | $ | 2,039 | $ | 69.25 | $ | 927 | $ | 30.86 | |||||||
Adjustments: | |||||||||||||||
Depreciation, depletion and amortization | $ | (507) | $ | (17.23) | $ | (487) | $ | (16.22) | |||||||
Impairment charges | (1,103) | (37.47) | (2) | (0.04) | |||||||||||
Gain on sale of assets | 3 | 0.13 | — | — | |||||||||||
Exploration expense | (4) | (0.12) | (9) | (0.30) | |||||||||||
Non-cash portion of compensation expense(2) | (13) | (0.47) | 22 | 0.75 | |||||||||||
Transition, restructuring and other costs(2) | (9) | (0.32) | (19) | (0.64) | |||||||||||
Fees paid to Sponsors(2) | — | — | (5) | (0.18) | |||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs | $ | 406 | $ | 13.77 | $ | 427 | $ | 14.23 | |||||||
Total consolidated equivalent volumes (MBoe) | 29,439 | 30,024 |
_______________________________________________________________ | |
(1) | Per unit costs are based on actual amounts rather than the rounded totals presented. |
(2) | Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans and transition, severance and other costs. Adjusted cash general and administrative expense are defined as Adjusted general and administrative expenses including capitalized labor.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense and non-GAAP adjusted cash general and administrative expense:
Actuals | |||||||||||||||||||||||
Year ended December 31, | 1Q 2019 Estimate | ||||||||||||||||||||||
2018 | 2017 | Low | High | ||||||||||||||||||||
Total | ($/Boe) | Total | ($/Boe) | ($/Boe) | ($/Boe) | ||||||||||||||||||
($ in millions, except per Boe costs) | |||||||||||||||||||||||
GAAP general and administrative expense | $ | 89 | $ | 3.03 | $ | 81 | $ | 2.69 | $ | 2.75 | $ | 3.15 | |||||||||||
Less non-cash compensation expense | (13) | (0.47) | 22 | 0.75 | (0.55) | (0.55) | |||||||||||||||||
Less transition, severance and other costs | (9) | (0.32) | (19) | (0.64) | — | — | |||||||||||||||||
Less fees paid to Sponsors | — | — | (5) | (0.18) | — | — | |||||||||||||||||
Adjusted general and administrative expense | $ | 67 | $ | 2.24 | $ | 79 | $ | 2.62 | $ | 2.20 | $ | 2.60 | |||||||||||
Capitalized labor | 14 | 0.49 | 23 | 0.77 | |||||||||||||||||||
Adjusted cash general and administrative expense | $ | 81 | $ | 2.73 | $ | 102 | $ | 3.39 |
_______________________________________________________ | |
(1) | Per unit costs are based on actual total amounts rather than the rounded totals presented. |
Net Debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents. At December 31, 2018, the company's net debt was approximately $4.4 billion (total debt $4,438 million less cash and cash equivalents of approximately $27 million). At December 31, 2017, the company's net debt was approximately $4.1 billion (total debt of approximately $4,093 million less cash and cash equivalents of approximately $27 million).
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted Cash Operating Costs ($ and per unit) and Adjusted Lease Operating Expense ($ and per unit) are used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and related per unit measures as well as Adjusted Oil and Gas Expenditures are used by management and investors as additional information as noted above. Net Debt is used by management for analysis of the company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Oil and Gas Expenditures, Adjusted Lease Operating Expense, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs and Adjusted Lease Operating Expense should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative expense and Adjusted Cash General and Administrative expense should not be used as an alternative to GAAP general and administrative expense. Adjusted Oil and Gas Expenditures should not be used as an alternative to operating, investing and/or financing cash flows, oil and gas capital expenditures or other measures of liquidity presented in accordance with GAAP. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Lease Operating Expense, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Lease Operating Expense, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and potential for sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the ability to develop proved undeveloped reserves; the future level of operating and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to generate sufficient cash flow to meet its debt obligations and commitments; the possibility that the company may not be able to continue as a going concern beginning in May 2020 if it is not successful in obtaining the necessary additional liquidity and/or if commodity prices do not appreciably increase; the company's limited ability to borrow under existing debt agreements to fund its operations; the company's ability to generate sufficient cash flow to meet it's debt obligations and commitments; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies, including potential downgrades; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Texas, March 11, 2019 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on Friday, March 15 to discuss its fourth quarter 2018 and full year 2018 financial and operational results. The company's fourth quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Thursday, March 14, 2019.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 4069531) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through April 15, 2019 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10129100). If you have any questions regarding the dial-in procedures, please contact Jordan Strauss at 713-997-6791.
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
Jordan.Strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Jan. 9, 2019 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today announced that on January 3, 2019, EP Energy was notified by the New York Stock Exchange of its noncompliance with continued listing standards because the average closing price of its class A common stock over a prior 30 consecutive trading day period had fallen below $1.00 per share, which is the minimum average closing price per share required to maintain listing on the NYSE.
In accordance with applicable NYSE procedures, EP Energy intends to notify the NYSE within ten business days of receipt of the notification of its intent to cure the deficiency and restore its compliance with the NYSE continued listing standards. EP Energy has a period of six months following the receipt of notice to regain compliance. EP Energy can regain compliance at any time during the six-month cure period if its common stock has a closing share price of at least $1.00 on the last trading day of any calendar month during the period and also has an average closing share price of at least $1.00 over the 30 trading day period ending on the last trading day of that month.
EP Energy's common stock will continue to be listed and traded on the NYSE during this six-month cure period, subject to the company's compliance with other continued listing requirements set forth in the NYSE Listed Company Manual.
The NYSE notification does not affect EP Energy's business operations or its Securities and Exchange Commission reporting requirements and does not result in a default under any of the company's material debt agreements.
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and potential for sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of operating and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Nov. 9, 2018 /PRNewswire/ -- Russell Parker, president and chief executive officer of EP Energy Corporation (NYSE: EPE), will present Wednesday, November 14, at the Bank of America Merrill Lynch Global Energy Conference in Miami, Florida. The presentation will begin at 4:00 p.m. EST, 3:00 p.m. CST with an audio webcast available on the Investor Center page of EP Energy's website at epenergy.com.
Presentation slides will be available prior to the presentation on the Investor Center page of the company's website.
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
Jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Nov. 7, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported third quarter 2018 financial and operational results.
3Q'18 Updates - Continuing to Execute Strategy with Focus on Value Creation and De-levering the Business
3Q'18 Demonstrating Capital Discipline and Improvement in Leverage Metrics
The third quarter of 2018 was the first quarter in the company's history to be free cash flow positive excluding hedging settlements. This was driven by a combination of improved capital efficiency, reduced costs, and higher oil prices.
3Q'18 Operating and Financial Performance Demonstrate Strong Execution
Below is a summary of third quarter 2018 results compared to the third quarter 2017:
3Q'17 | 3Q'18 | 3Q'18 vs. 3Q'17 | |
Oil Production (MBbls/d) | 45.1 | 46.4 | + 3% |
Equivalent Production (MBoe/d) | 81.0 | 80.4 | - 1% |
Percent Oil (%) | 55.7 | 57.7 | + 4% |
Produced Volumes (MBoe/d)1 | 81.0 | 81.7 | + 1% |
LOE per Unit ($/Boe) | 5.66 | 6.16 | + 9% |
Adjusted LOE per Unit ($/Boe)2,3
| 5.66 | 5.88 | + 4% |
Lease Operating Expense ($MM) | 42.2 | 45.6 | + 8% |
Adjusted Lease Operating Expense ($MM)2,3 | 42.2 | 43.5 | + 3% |
Adjusted G&A expense per Unit ($/Boe)2 | 2.63 | 2.05 | - 22% |
Net (Loss) ($MM) | (72) | (44) | + 39% |
Adjusted EBITDAX ($MM)2 | 159 | 214 | + 35% |
Oil and Gas Expenditures ($MM) | 162 | 201 | + 24% |
Adjusted Oil and Gas Expenditures (excl. Acquisitions and Other ) ($MM)2 | 133 | 133 | 0% |
1 | Produced volumes include 8 MMcf/d of reinjected gas volumes used in operations during the 3Q'18. |
2 | See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
3 | Does not include approximately $2 million or $0.28 per Boe for the quarter ended September 30, 2018 of adjustments under a joint venture agreement. |
Unlocking Value in Utah - First Horizontal Well Delivers Most Productive Well in Company History
The company has renamed its position in the Uinta Basin to Northeastern Utah or NEU. In the third quarter of 2018, the company produced 17.5 MBoe/d, including 12.0 MBbls/d of oil, a four percent decrease from the third quarter of 2017, respectively. EP Energy operated two joint venture drilling rigs and completed (frac'd) six gross wells and two net wells in the third quarter of 2018. Total capital invested in NEU in the third quarter of 2018 was $35 million excluding acquisitions.
In the third quarter of 2018, the company completed its first two horizontal wells in NEU. The Duchesne City 1-25-26-C5-2H well was drilled to a lateral length of approximately 9,800 feet and has produced 110,000 barrels of oil after 78 days, making it the most productive oil well completed in the company's history. The second well, Duchesne City 1-25-26-C5-1H, was drilled to a lateral length of 7,900 feet and has produced 60,000 barrels of oil after 78 days and is in the top 6% of oil producing wells for the company.
In the fourth quarter of 2018, the company plans to take core samples to assess the potential of horizontal development over the company's entire 159,000 net acres across multiple benches. Additionally, the company has 57 horizontal permits in process and will focus on NEU horizontal wells in 2019 due to their strong productivity.
Eagle Ford: Significant Oil Growth and Progress on Capital Efficiency Initiatives
The company produced 35.8 MBoe/d, including 25.6 MBbls/d of oil in the third quarter of 2018, a nine percent and 28% increase from the third quarter of 2017, respectively. EP Energy averaged approximately three drilling rigs, invested $92 million excluding acquisition capital and completed (frac'd) 22 gross and 10 net wells in the third quarter of 2018.
EP Energy continued to increase the scale of EOR operations in the third quarter and into the fourth quarter of 2018. In our first EOR pilot, we completed two injection cycles and expect to complete 2-3 more cycles across the three pilot areas by year-end. In August, the company operationalized its second pilot in the north end of its La Salle acreage. In October, the third EOR pilot became operational in the retrograde condensate window in the southern end of its acreage position. In total, the company recycled approximately 8 MMcfe/d of gas in the third quarter of 2018. The goal for the EOR projects is to significantly increase recoverable reserves and lower finding and development (F&D) costs.
Wells drilled in 2018 with new completion designs have exceeded pre-2018 offset wells by eight percent on net revenue per investment (RPI) as of 160 days. This group of wells are expected to outperform their offsets by 20% based on RPI. In addition, the company completed its two longest Eagle Ford laterals in company history. Both wells are currently in flow back, and we expect to provide a performance update in 4Q'18. The company continues to modify completion designs, lateral lengths and spacing for each pad to maximize returns and minimize F&D costs.
In the fourth quarter of 2018, the company plans to run three rigs and complete 21 wells focused on development in the southern and eastern portion of the La Salle acreage.
Permian: Optimizations Lead to Second Most Productive Well Since Program Inception
In the third quarter of 2018, the company produced 27.1 MBoe/d, including 8.8 MBbls/d of oil, a nine percent and 30% decrease from the third quarter of 2017, respectively. In the third quarter of 2018, the company invested $7 million (excluding drilling JV adjustments) and completed (frac'd) three gross and two net wells.
In 2018, the company applied a new completion design that resulted in the second most productive oil well in program history. Two additional wells with the enhanced design, which came online in September, are currently performing in-line with the improvement.
The company maintains ample take-away capacity out of the basin through contractual agreements with third-party processors and marketing companies. In addition, the company has 100% of its Midland to Cushing basis exposure hedged in 2018 at -$1.02 per barrel and approximately one-third of its Midland to Cushing basis exposure hedged in 2019 at -$6.47 per barrel.
Multi-year Commodity Hedge Program: Well Positioned in 2018 and ~60 Percent Hedged in 20191
EP Energy maintains a solid hedge program, which provides continued commodity price protection. A summary of the company's current open hedge positions is listed below:
2018 | 2019 | |||||||
Total Fixed Price Hedges | ||||||||
Oil volumes (MMBbls)2 | 3.8 | 9.7 | ||||||
Average ceiling price ($/Bbl) | $ | 63.96 | $ | 67.82 | ||||
Average floor price ($/Bbl) | $ | 58.45 | $ | 58.09 | ||||
Natural Gas volumes (TBtu) | 7.0 | 7.0 | ||||||
Average price ($/MMBtu) | $ | 3.04 | $ | 2.97 |
Note: Positions are as of October 22, 2018 (Contract months: September 1, 2018 - Forward) | |
1 | Percentage based on mid-point of 2018 production guidance |
2 | 2018 and 2019 positions include WTI three way collars of 2.2 MMBbls and 7.3 MMBbls, respectively, and WTI collars of 0.3 MMBbls in 2018 and 1.6 MMBbls in 2019. |
Liquidity - Financial Flexibility Continues to Improve with Successful Redetermination of RBL Facility
The company ended the quarter with $56 million in cash and zero borrowings on the RBL Facility, resulting in $666 million of available liquidity and $4.3 billion of net debt (total debt of $4.4 billion less cash of $56 million). In November 2018, the banks reaffirmed the current borrowing base of $1.4 billion and commitments of $629 million.
2018 Outlook Maintained
The table below summarizes the company's current operational and financial guidance for the full year 2018.
3Q'18 YTD | FY 2018 Estimate | |||
Production Volumes | ||||
Oil production (MBbls/d) | 46.4 | 45 – 47 | ||
Total production (MBoe/d) | 81.0 | 79 – 82 | ||
Oil & Gas Expenditures ($ million) | $545 | $630 – $6701 | ||
Eagle Ford | $349 | ~65% | ||
Permian | $98 | ~15% | ||
NEU | $98 | ~20%2 | ||
Average Gross Drilling Rigs | ||||
Eagle Ford | 2.8 | 3 | ||
Permian | 0.4 | - | ||
NEU | 2.0 | 2 | ||
Operating Costs | ||||
Lease operating expense ($/Boe) | $5.53 | $5.00 – $5.70 | ||
Reported G&A expense ($/Boe) | $3.09 | $2.90 – $3.25 | ||
Adjusted G&A expense ($/Boe)3,5 | $2.33 | $2.30 – $2.60 | ||
Transportation ($/Boe) | $3.44 | $3.15 – $3.45 | ||
Taxes, other than income ($/Boe)4 | $2.86 | $2.75 – $2.85 | ||
DD&A ($/Boe) | $17.00 | $17.00 – $17.50 |
1 | Full year 2018 includes ~$120 million non-drill capital including: ~$55 million for general equipment, ~$20 million for capitalized G&A and interest, ~$20 million for enhanced facility projects, ~$15 million for EOR projects, and ~$10 million for leasing and seismic, and does not include acquisition costs or $22 million drilling joint venture adjustment |
2 | Full year 2018 NEU capital includes ~81 recompletions for $47 million. |
3 | Adjusted G&A represents G&A expense less approximately $0.44 per Boe of non-cash compensation expense and $0.32 per Boe in transition, severance and other costs in YTD 3Q'18 reported G&A and $0.60 - $0.65 per Boe of non-cash compensation expense in FY 2018 Estimate. |
4 | Severance taxes estimates are based on current WTI prices. |
5 | See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on November 8, 2018, to discuss its third quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials relating to the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID#8791565) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through December 15, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID#10124370).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
The following table provides the company's production results, average realized prices, results of operations and certain non-GAAP financial measures for the periods presented. See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms.
Quarter ended September 30, | |||||
2018 | 2017 | ||||
Oil Sales Volumes (MBbls/d) | |||||
Eagle Ford | 25.6 | 20.0 | |||
Permian | 8.8 | 12.6 | |||
NEU | 12.0 | 12.5 | |||
Total Oil Sales Volumes | 46.4 | 45.1 | |||
Natural Gas Sales Volumes (MMcf/d) | |||||
Eagle Ford | 30 | 37 | |||
Permian | 58 | 55 | |||
NEU | 33 | 34 | |||
Total Natural Gas Sales Volumes | 121 | 126 | |||
NGLs Sales Volumes (MBbls/d) | |||||
Eagle Ford | 5.2 | 6.7 | |||
Permian | 8.7 | 8.2 | |||
NEU | — | — | |||
Total NGLs Sales Volumes | 13.9 | 14.9 | |||
Equivalent Sales Volumes (MBoe/d) | |||||
Eagle Ford | 35.8 | 32.9 | |||
Permian | 27.1 | 29.9 | |||
NEU | 17.5 | 18.2 | |||
Total Equivalent Sales Volumes | 80.4 | 81.0 | |||
Net loss ($ in millions) | (44) | (72) | |||
Adjusted EBITDAX ($ in millions) | 214 | 159 | |||
Basic and diluted net loss per common share ($) | (0.18) | (0.29) | |||
Adjusted EPS ($) | (0.04) | (0.12) | |||
Capital Expenditures ($ in millions)(1) | 201 | 162 | |||
Adjusted Capital Expenditures ($ in millions) | 133 | 133 | |||
Total Operating Expenses ($/Boe) | 33.13 | 31.79 | |||
Adjusted Cash Operating Costs ($/Boe) | 15.20 | 14.73 | |||
Depreciation, depletion and amortization rate ($/Boe) | 17.11 | 15.92 | |||
Average realized prices(2) | |||||
Oil price on physical sales ($/Bbl) | 66.61 | 45.49 | |||
Oil, including financial derivatives ($/Bbl)(3) | 63.37 | 51.75 | |||
Natural gas price on physical sales ($/Mcf) | 1.34 | 2.26 | |||
Natural gas, including financial derivatives ($/Mcf)(3) | 1.69 | 2.49 | |||
NGLs price on physical sales ($/Bbl) | 27.74 | 18.98 | |||
NGLs, including financial derivatives ($Bbl)(3) | 24.79 | 18.45 |
(1) | The quarter ended September 30, 2018 includes $46 million and $22 million, respectively, of acquisition capital and capital adjustments under a joint venture agreement. The quarter ended September 30, 2017 includes $29 million of acquisition capital. | ||||
(2) | Oil and natural gas prices on physical sales reflect operating revenues for oil and natural gas reduced by oil and natural gas purchases associated with managing our physical sales. | ||||
(3) | Prices per unit are calculated using total financial derivative cash settlements. |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF INCOME (In millions) (Unaudited) | |||||||
Quarter ended September 30, | |||||||
2018 | 2017 | ||||||
Operating revenues | |||||||
Oil | $ | 287 | $ | 189 | |||
Natural gas | 15 | 27 | |||||
NGLs | 36 | 26 | |||||
Financial derivatives | (44) | (23) | |||||
Total operating revenues | 294 | 219 | |||||
Operating expenses | |||||||
Oil and natural gas purchases | 3 | — | |||||
Transportation costs | 25 | 29 | |||||
Lease operating expense | 46 | 42 | |||||
General and administrative | 21 | 25 | |||||
Depreciation, depletion and amortization | 127 | 118 | |||||
Gain on sale of assets | (1) | — | |||||
Impairment charges | — | 1 | |||||
Exploration and other expense | 2 | 6 | |||||
Taxes, other than income taxes | 22 | 16 | |||||
Total operating expenses | 245 | 237 | |||||
Operating income (loss) | 49 | (18) | |||||
Other income | 2 | — | |||||
Gain on extinguishment/modification of debt | — | 24 | |||||
Interest expense | (95) | (80) | |||||
Loss before income taxes | (44) | (74) | |||||
Income tax benefit | — | 2 | |||||
Net loss | $ | (44) | $ | (72) |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED BALANCE SHEETS (In millions) (Unaudited) | ||||||||
September 30, 2018 | December 31, 2017 | |||||||
ASSETS | ||||||||
Current assets(1) | $ | 315 | $ | 466 | ||||
Property, plant and equipment, net(2) | 4,913 | 4,422 | ||||||
Other non-current assets | 11 | 12 | ||||||
Total assets | $ | 5,239 | $ | 4,900 | ||||
LIABILITIES AND EQUITY | ||||||||
Current liabilities | $ | 563 | $ | 448 | ||||
Long-term debt, net of debt issue costs | 4,295 | 4,022 | ||||||
Other non-current liabilities | 64 | 38 | ||||||
Total stockholders' equity | 317 | 392 | ||||||
Total liabilities and equity | $ | 5,239 | $ | 4,900 |
(1) | Balance as of December 31, 2017 includes $172 million of assets held for sale. | ||||
(2) | Balance is net of accumulated depreciation, depletion and amortization of $3,554 million and $3,179 million as of September 30, 2018 and December 31, 2017, respectively. |
EP ENERGY CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (In millions) (Unaudited) | |||||||
Nine months ended September 30, | |||||||
2018 | 2017 | ||||||
Net loss | $ | (84) | $ | (122) | |||
Adjustments to reconcile net loss to net cash provided by operating activities | |||||||
Non-cash expenses | 349 | 410 | |||||
Asset and liability changes | 115 | 10 | |||||
Net cash provided by operating activities | 380 | 298 | |||||
Net cash used in investing activities | (659) | (434) | |||||
Net cash provided by financing activities | 290 | 137 | |||||
Change in cash, cash equivalents and restricted cash | 11 | 1 | |||||
Cash, cash equivalents and restricted cash - beginning of period | 45 | 20 | |||||
Cash, cash equivalents and restricted cash - end of period | $ | 56 | $ | 21 |
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment/modification of debt, impairment charges, other costs that affect comparability, including transition, severance and other costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net income (loss) per share to Adjusted EPS:
Quarter ended September 30, 2018 | |||||||||||
Pre Tax | After Tax | Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss | $ | (44) | $ | (0.18) | |||||||
Adjustments(2) | |||||||||||
Impact of financial derivatives(3) | $ | 30 | $ | 23 | $ | 0.09 | |||||
Transition, severance and other costs | 1 | 1 | 0.01 | ||||||||
Valuation allowance on deferred tax assets | 10 | 0.04 | |||||||||
Total adjustments | $ | 31 | $ | 34 | $ | 0.14 | |||||
Adjusted EPS | $ | (0.04) | |||||||||
Diluted weighted average shares | 248 | ||||||||||
Quarter ended September 30, 2017 | |||||||||||
Pre Tax | After Tax | Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss | $ | (72) | $ | (0.29) | |||||||
Adjustments(2) | |||||||||||
Impact of financial derivatives(3) | $ | 50 | $ | 32 | $ | 0.13 | |||||
Gain on extinguishment of debt | (24) | (15) | (0.06) | ||||||||
Impairment charges | 1 | — | — | ||||||||
Valuation allowance on deferred tax assets | 24 | 0.10 | |||||||||
Total adjustments | $ | 27 | $ | 41 | $ | 0.17 | |||||
Adjusted EPS | $ | (0.12) | |||||||||
Diluted weighted average shares | 246 |
(1) | Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | ||||
(2) | All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. | ||||
(3) | Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
Free Cash Flow is defined as Adjusted EBITDAX less hedge settlements, adjusted oil and gas expenditures, and cash interest calculated on an annualized basis. Below is a reconciliation of our net cash provided by operating activities to Free Cash Flow:
Quarter ended | ||||
($ in millions) | ||||
Net cash provided by operating activities(1) | $ | 163 | ||
Interest expense, net | 95 | |||
Working capital and other | (44) | |||
Adjusted EBITDAX | $ | 214 | ||
Less: Hedge settlements | 14 | |||
Less: Adjusted oil and gas expenditures(2) | (133) | |||
Less: One quarter of annualized cash interest | (91) | |||
Free Cash Flow | $ | 4 | ||
Net cash used in investing activities(1) | $ | (205) | ||
Net cash used in financing activities(1) | $ | (1) |
(1) | Calculated as the difference between YTD September 30, 2018 and YTD June 30, 2018 GAAP Statement of Cash Flow amounts. | ||||
(2) | Adjusted oil and gas expenditures excludes $46 million of acquisition capital and $22 million of capital adjustments under a joint venture agreement. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, gains and losses on extinguishment/modification of debt, gains and/or losses on sale of assets and impairment charges.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter ended September 30, | ||||||||
2018 | 2017 | |||||||
($ in millions) | ||||||||
Net loss | $ | (44) | $ | (72) | ||||
Income tax benefit | — | (2) | ||||||
Interest expense, net of capitalized interest | 95 | 80 | ||||||
Depreciation, depletion and amortization | 127 | 118 | ||||||
Exploration expense | 1 | 3 | ||||||
EBITDAX | 179 | 127 | ||||||
Mark-to-market on financial derivatives(1) | 44 | 23 | ||||||
Cash settlements and cash premiums on financial derivatives(2) | (14) | 27 | ||||||
Non-cash portion of compensation expense(3) | 5 | 5 | ||||||
Transition, severance and other costs(4) | 1 | — | ||||||
Gain on sale of assets | (1) | — | ||||||
Gain on extinguishment/modification of debt | — | (24) | ||||||
Impairment charges | — | 1 | ||||||
Adjusted EBITDAX | $ | 214 | $ | 159 |
(1) | Represents the income statement impact of financial derivatives. | ||||
(2) | Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | ||||
(3) | Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. | ||||
(4) | Reflects transition and severance costs related to workforce reductions. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains/losses on sale of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, severance and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to our existing assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended September 30, | ||||||||||||||||
2018 | 2017 | |||||||||||||||
Total | Per-Unit(1) | Total | Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Oil and natural gas purchases | $ | 3 | $ | 0.36 | $ | — | $ | — | ||||||||
Transportation costs | 25 | 3.41 | 29 | 3.91 | ||||||||||||
Lease operating expense | 46 | 6.16 | 42 | 5.66 | ||||||||||||
General and administrative | 21 | 2.91 | 25 | 3.28 | ||||||||||||
Depreciation, depletion and amortization | 127 | 17.11 | 118 | 15.92 | ||||||||||||
Impairment charges | — | — | 1 | 0.09 | ||||||||||||
Gain on sale of assets | (1) | (0.13) | — | — | ||||||||||||
Exploration and other expense | 2 | 0.29 | 6 | 0.83 | ||||||||||||
Taxes, other than income taxes | 22 | 3.02 | 16 | 2.10 | ||||||||||||
Total operating expenses | $ | 245 | $ | 33.13 | $ | 237 | $ | 31.79 | ||||||||
Adjustments: | ||||||||||||||||
Depreciation, depletion and amortization | $ | (127) | $ | (17.11) | $ | (118) | $ | (15.92) | ||||||||
Impairment charges | — | — | (1) | (0.09) | ||||||||||||
Exploration expense | (1) | (0.09) | (3) | (0.40) | ||||||||||||
Gain on sale of assets | 1 | 0.13 | — | — | ||||||||||||
Non-cash portion of compensation expense(2) | (5) | (0.70) | (5) | (0.65) | ||||||||||||
Transition, severance and other costs(2) | (1) | (0.16) | — | — | ||||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs | $ | 112 | $ | 15.20 | $ | 110 | $ | 14.73 | ||||||||
Total consolidated equivalent volumes (MBoe) | 7,401 | 7,456 |
(1) | Per unit costs are based on actual total amounts rather than the rounded totals presented. | ||||
(2) | Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans and transition, severance and other costs. Adjusted cash general and administrative expense are defined as Adjusted general and administrative expenses including capitalized labor.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense and non-GAAP adjusted cash general and administrative expense:
Actuals | FY 2018 Estimate | ||||||||||||||||||||||
Quarter ended September 30, | |||||||||||||||||||||||
2018 | 2017 | Low | High | ||||||||||||||||||||
Total | ($/Boe) | Total | ($/Boe) | ($/Boe) | ($/Boe) | ||||||||||||||||||
($ in millions, except per Boe costs) | |||||||||||||||||||||||
GAAP general and administrative expense | $ | 21 | $ | 2.91 | $ | 25 | $ | 3.28 | $ | 2.90 | $ | 3.25 | |||||||||||
Less non-cash compensation expense | 5 | 0.70 | 5 | 0.65 | 0.60 | 0.65 | |||||||||||||||||
Less transition, severance and other costs | 1 | 0.16 | — | — | — | — | |||||||||||||||||
Adjusted general and administrative expense | $ | 15 | $ | 2.05 | $ | 20 | $ | 2.63 | $ | 2.30 | $ | 2.60 | |||||||||||
Capitalized labor | 4 | 0.47 | 6 | 0.79 | |||||||||||||||||||
Adjusted cash general and administrative expense | $ | 19 | $ | 2.52 | $ | 26 | $ | 3.42 |
(1) | Per unit costs are based on actual total amounts rather than the rounded totals presented. |
Net Debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents.
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Free Cash Flow is used by management and we believe provides investors with useful information for analysis of the company's ability to internally fund capital expenditure and to service or incur additional debt. Adjusted Cash Operating Costs ($ and per unit) and Adjusted Lease Operating Expense ($ and per unit) are used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and related per unit measures as well as Adjusted Oil and Gas Expenditures are used by management and investors as additional information as noted above. Net Debt is used by management for analysis of the company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Oil and Gas Expenditures, Adjusted Lease Operating Expense, Free Cash Flow, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs and Adjusted Lease Operating Expense should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative expense and Adjusted Cash General and Administrative expense should not be used as an alternative to GAAP general and administrative expense. Free Cash Flow and Adjusted Oil and Gas Expenditures should not be used as an alternative to operating, investing and/or financing cash flows, oil and gas capital expenditures or other measures of liquidity presented in accordance with GAAP. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Lease Operating Expense, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense, Free Cash Flow and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted Lease Operating Expense, Adjusted Oil and Gas Expenditures, Adjusted General and Administrative expense, Adjusted Cash General and Administrative expense, Free Cash Flow and Net Debt should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and potential for sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of operating and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Oct. 29, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on Thursday, November 8 to discuss its third quarter 2018 financial and operational results. The company's third quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, November 7, 2018.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 8791565) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through December 15, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10124370). If you have any questions regarding the dial-in procedures, please contact Jordan Strauss at 713-997-2137.
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Jordan Strauss
713-997-2137
jordan.strauss@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Aug. 9, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported second quarter 2018 financial and operational results.
2Q'18 Updates - Executing Strategy to Drive Long-Term Value Creation
2Q'18 Results Continue to Show Positive Change With New Leadership Team
The second quarter results continue to demonstrate improvement in operational and financial metrics. The company has increased oil production and Adjusted EBITDAX, while continuing to reduce lease operating and general and administrative costs. Below is a summary of second quarter 2018 results compared to the last three quarters.
3Q'17 |
4Q'17 |
1Q'18 |
2Q'18 |
2Q'18 vs. 3Q'17 | |
Oil Production (MBbls/d) |
45.1 |
43.6 |
45.4 |
47.2 |
+5% |
Equivalent Production (MBoe/d) |
81.0 |
80.6 |
80.1 |
82.5 |
+2% |
Percent Oil (%) |
55.7 |
54.1 |
56.7 |
57.2 |
+3% |
LOE per Unit ($/Boe) |
5.66 |
5.60 |
5.48 |
4.95 |
-13% |
Lease Operating Expense ($MM) |
42.2 |
41.5 |
39.5 |
37.6 |
-11% |
Boe/d per G&A Headcount |
229 |
238 |
253 |
321 |
+40% |
Net (Loss) Income ($MM) |
(72) |
(72) |
18 |
(58) |
-19% |
Adjusted EBITDAX ($MM)1 |
159 |
181 |
189 |
215 |
+35% |
1 See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
Eagle Ford: Increase in Oil Production and Improvement in Capital Efficiency
The company produced 39.2 MBoe/d, including 25.8 MBbls/d of oil in the second quarter of 2018, a nine percent and eight percent increase from the first quarter of 2018, respectively. Production in the second quarter benefited from the increase in activities in early 2018, improved production results from new well designs and completion techniques, and acquisition properties. EP Energy averaged three drilling rigs, invested $122 million and completed (frac'd) 17 gross and net wells in the second quarter of 2018 in its Eagle Ford program.
EP Energy continues to make great progress on its EOR pilot project. In the second quarter of 2018, EP Energy initialized its second injection cycle and plans for two more pilot projects to be operational by year end. Due to the promising long-term value creation potential of the project, the company has decided to accelerate the timing, allocate incremental capital, and increase the number of pilot projects above what was originally planned. The expansion of the EOR pilot projects will allow the company to accelerate the delineation of the EOR applicability across the company's Eagle Ford position.
The company continues to optimize completion designs for each pad to maximize returns and minimize finding and development costs. Based on new wells completed during 1Q'18, the company estimates an approximately 20% improvement in recoverable reserves per drilling and completion capital invested versus offset wells completed prior to 2018.
In July, the company drilled two 16,000 foot lateral wells, which are the longest laterals in company history. This is an important step forward in the Eagle Ford asset as the company looks to develop remaining acreage in the most capitally efficient manner going forward. The company believes 15,000 foot laterals will be the future of development for a large portion of the remaining acreage. The step change from 7,500 foot laterals creates a significant savings in total infrastructure costs. The company expects the average lateral length for the second half of 2018 to be 16% greater than the first half of 2018. In the second half of 2018, the company plans to reallocate capital from the Permian to the Eagle Ford to take advantage of the improved returns and capital efficiency driven by the favorable LLS and Brent pricing.
Permian: Reducing Operating Costs
In the second quarter of 2018, the company produced 26.5 MBoe/d, including 9.7 MBbls/d of oil, effectively flat compared to the first quarter of 2018. In the second quarter of 2018, the company averaged approximately one drilling rig, invested $48 million in capital and completed (frac'd) 13 gross and nine net wells.
In the second quarter of 2018, the company constructed and operationalized its first produced water pond for recycle use. The facility became operational in April and is lowering operating costs by approximately $1.54/Bbl of water. In addition, the facility lowers completion costs by providing a low-cost direct source of water for completion operations instead of trucking in fresh water saving approximately $0.45/Bbl of water.
The company maintains ample take-away capacity out of the basin through contractual agreements with third-party processors and marketing companies. In addition, EP Energy has 100% of its Midland to Cushing basis exposure hedged in 2018 at -$1.02 per barrel.
Altamont: Two Horizontal Wells Drilled and First Quarter Recompletion Record Broken
In the second quarter of 2018, the company produced 16.8 MBoe/d, including 11.7 MBbls/d of oil, effectively flat compared to the first quarter of 2018. The gas production was impacted by downtime related to unexpected plant maintenance during May 2018.
EP Energy operated two joint venture drilling rigs and completed (frac'd) seven gross wells and two net wells in the second quarter of 2018. Total capital invested in the Altamont program in the second quarter of 2018 was $33 million. The company also accelerated its high-return recompletion program, successfully recompleting 29 wells during the quarter, which broke the company's all-time record from the first quarter of 2018.
The company spud and rig released its first two horizontal wells during the quarter. The two horizontal wells have an average lateral length of 9,000 feet. The company has commenced completion operations and expects to initialize flowback on both wells over the next 30-60 days. In addition, the company expects to drill two incremental horizontal wells in the third quarter to accelerate the delineation of the horizontal potential of the field.
Multi-year Commodity Hedge Program: Well Positioned in 2018 and ~51 Percent Hedged in 20191
EP Energy maintains a solid hedge program, which provides continued commodity price protection. A summary of the company's current open hedge positions is listed below:
2018 |
2019 | |||||||
Total Fixed Price Hedges |
||||||||
Oil volumes (MMBbls)2 |
7.6 |
8.6 |
||||||
Average ceiling price ($/Bbl) |
$ |
63.96 |
$ |
66.60 |
||||
Average floor price ($/Bbl) |
$ |
58.45 |
$ |
57.63 |
||||
Natural Gas volumes (TBtu) |
12.9 |
7.3 |
||||||
Average price ($/MMBtu) |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of August 7, 2018 (Contract months: June 30, 2018 - Forward) |
1 Percentage based on mid-point of 2018 production guidance |
2 2018 and 2019 positions include WTI three way collars of 4.5 MMBbls and 6.6 MMBbls, respectively, and WTI collars of 0.6 MMBbls in 2018 and 1.3 MMBbls in 2019. |
Liquidity - Financial Flexibility Significantly Improved
The company ended the quarter with $708 million of available liquidity and $4.3 billion of net debt (total debt of $4.4 billion less cash of $98 million). In May 2018, the company issued $1 billion of senior secured notes and used the proceeds to fully repay the RBL Facility. In addition, the company amended its RBL Facility agreement by extending the maturity date from May 2019 to November 2021. The maintenance covenant was also amended to a maximum ratio of first-lien debt to EBITDAX of 2.25 to 1.00 through maturity.
2018 Outlook Updated to Reflect Reallocation of Capital For Long-Term Value Creation
The table below summarizes the company's current operational and financial guidance for the second half of 2018. The company has increased the full year 2018 Oil & Gas Expenditures midpoint, excluding acquisitions, to $650 million. The increase is driven by incremental activity during the second half of the year that will result in incremental 2019 EBITDAX growth. The company expects to increase gross completions six percent from the original guidance, add a third EOR pilot, and two incremental Altamont horizontal wells. The company has increased the full year Eagle Ford capital allocation from ~50% to ~65%.
Due to the acceleration of activities in the Eagle Ford, and changing the development approach, the company expects to temporarily shut-in more recently completed offset wells than planned during the second half of 2018. These intentional shut-ins will temporarily lower near-term production, but will reduce the future impact of offset frac interference and provide greater long-term value over the life of the field benefiting 2019 and beyond production and cash flow. In addition, the company's original guidance was based on $55 per barrel for West Texas Intermediate (WTI) crude. Given the rise in current commodity prices, the company expects higher cash flows. However, the company will experience an increased burden in the Permian sliding scale royalty agreement, resulting in approximately 500 Bbls/d lower volumes during 2Q'18 to 4Q'18.
1H'18 |
2H'18 |
FY 2018 | ||
Production Volumes |
||||
Oil production (MBbls/d) |
46.3 |
45 - 47 |
45 – 47 | |
Total production (MBoe/d) |
81.3 |
79 – 82 |
79 – 82 | |
Oil & Gas Expenditures ($ million) |
$411 |
$220 – $260 |
$630 – $6701 | |
Eagle Ford |
$257 |
~65% | ||
Permian |
$91 |
~15% | ||
Altamont |
$63 |
~20%2 | ||
Average Gross Drilling Rigs |
||||
Eagle Ford |
3 |
3 | ||
Permian |
0.6 |
- | ||
Altamont |
2 |
2 | ||
Operating Costs |
||||
Lease operating expense ($/Boe) |
$5.21 |
$5.00 – $5.70 | ||
Reported G&A expense ($/Boe) |
$3.17 |
$2.90 – $3.25 | ||
Adjusted G&A expense ($/Boe)3 |
$2.47 |
$2.30 – $2.60 | ||
Transportation and commodity purchases ($/Boe) |
$3.46 |
$3.15 – $3.45 | ||
Taxes, other than income ($/Boe)4 |
$2.78 |
$2.75 – $2.85 | ||
DD&A ($/Boe) |
$16.95 |
$17.00 – $17.50 |
1 Full year 2018 includes ~$120 million non-drill capital including: ~$55 million for general equipment, ~$20 million for capitalized G&A and interest, ~$20 million for enhanced facility projects, ~$15 million for EOR projects, and ~$10 million for leasing and seismic, and does not include acquisition costs. | |
2 Full year 2018 Altamont capital includes ~81 recompletions for $47 million. | |
3 Adjusted G&A represents G&A expense less approximately $0.30 per Boe of non-cash compensation expense and $0.40 per Boe in transition, restructuring and other costs in 1H'18 reported G&A and $0.60 - $0.65 per Boe of non-cash compensation expense in FY 2018 Estimate. | |
4 Severance taxes estimates are based on current WTI prices. |
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on August 10, 2018, to discuss its second quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials relating to the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID#6173767) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through September 14, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID#10122575).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
The following table provides the company's production results, average realized prices, results of operations and certain non-GAAP financial measures for the periods presented.
Quarter ended | |||||||||
June 30, |
March 31, |
September 30, | |||||||
Oil Sales Volumes (MBbls/d) |
|||||||||
Eagle Ford |
25.8 |
24.0 |
20.0 |
||||||
Permian |
9.7 |
9.8 |
12.6 |
||||||
Altamont |
11.7 |
11.6 |
12.5 |
||||||
Total Oil Sales Volumes |
47.2 |
45.4 |
45.1 |
||||||
Natural Gas Sales Volumes (MMcf/d) |
|||||||||
Eagle Ford |
40 |
36 |
37 |
||||||
Permian |
54 |
56 |
55 |
||||||
Altamont |
30 |
34 |
34 |
||||||
Total Natural Gas Sales Volumes |
124 |
126 |
126 |
||||||
NGLs Sales Volumes (MBbls/d) |
|||||||||
Eagle Ford |
6.8 |
5.9 |
6.7 |
||||||
Permian |
7.8 |
7.8 |
8.2 |
||||||
Altamont |
— |
— |
— |
||||||
Total NGLs Sales Volumes |
14.6 |
- |
13.7 |
14.9 |
|||||
Equivalent Sales Volumes (MBoe/d) |
|||||||||
Eagle Ford |
39.2 |
35.9 |
32.9 |
||||||
Permian |
26.5 |
27.0 |
29.9 |
||||||
Altamont |
16.8 |
17.2 |
18.2 |
||||||
Total Equivalent Sales Volumes |
82.5 |
80.1 |
81.0 |
||||||
Net (loss) income ($ in millions) |
(58) |
18 |
(72) |
||||||
Adjusted EBITDAX ($ in millions) |
215 |
189 |
159 |
||||||
Basic and diluted net (loss) income per common share ($) |
(0.23) |
0.07 |
(0.29) |
||||||
Adjusted EPS ($) |
(0.01) |
(0.07) |
(0.12) |
||||||
Capital Expenditures ($ in millions)(1) |
203 |
208 |
162 |
||||||
Total Operating Expenses ($/Boe) |
32.20 |
31.11 |
31.79 |
||||||
Adjusted Cash Operating Costs ($/Boe) |
13.85 |
13.97 |
14.73 |
||||||
Depreciation, depletion and amortization rate ($/Boe) |
17.20 |
16.69 |
15.92 |
||||||
Average realized prices(2) |
|||||||||
Oil price on physical sales ($/Bbl) |
65.53 |
61.56 |
45.49 |
||||||
Oil, including financial derivatives ($/Bbl)(3) |
62.30 |
58.86 |
51.75 |
||||||
Natural gas price on physical sales ($/Mcf) |
1.58 |
1.94 |
2.26 |
||||||
Natural gas, including financial derivatives ($/Mcf)(3) |
1.96 |
2.03 |
2.49 |
||||||
NGLs price on physical sales ($/Bbl) |
22.65 |
20.93 |
18.98 |
||||||
NGLs, including financial derivatives ($Bbl)(3) |
22.07 |
20.91 |
18.45 |
||||||
(1) |
The quarters ended June 30, 2018 and March 31, 2018 do not include $16 million and $248 million, respectively, of acquisition capital. | ||||
(2) |
Oil and natural gas prices on physical sales reflect operating revenues for oil and natural gas reduced by oil and natural gas purchases associated with managing our physical sales. | ||||
(3) |
Prices per unit are calculated using total financial derivative cash settlements. |
EP ENERGY CORPORATION | |||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF INCOME | |||||||||||
(In millions) | |||||||||||
(Unaudited) | |||||||||||
Quarter ended | |||||||||||
June 30, |
March 31, |
September 30, | |||||||||
Operating revenues |
|||||||||||
Oil |
$ |
281 |
$ |
252 |
189 |
||||||
Natural gas |
18 |
22 |
27 |
||||||||
NGLs |
30 |
26 |
26 |
||||||||
Financial derivatives |
(64) |
(14) |
(23) |
||||||||
Total operating revenues |
265 |
286 |
219 |
||||||||
Operating expenses |
|||||||||||
Oil and natural gas purchases |
— |
— |
— |
||||||||
Transportation costs |
26 |
25 |
29 |
||||||||
Lease operating expense |
38 |
39 |
42 |
||||||||
General and administrative |
28 |
19 |
25 |
||||||||
Depreciation, depletion and amortization |
129 |
120 |
118 |
||||||||
Impairment charges |
— |
— |
1 |
||||||||
Exploration and other expense |
— |
1 |
6 |
||||||||
Taxes, other than income taxes |
21 |
20 |
16 |
||||||||
Total operating expenses |
242 |
224 |
237 |
||||||||
Operating income (loss) |
23 |
62 |
(18) |
||||||||
Gain on extinguishment/modification of debt |
7 |
41 |
24 |
||||||||
Interest expense |
(88) |
(85) |
(80) |
||||||||
(Loss) income before income taxes |
(58) |
18 |
(74) |
||||||||
Income tax benefit |
— |
— |
2 |
||||||||
Net (loss) income |
$ |
(58) |
$ |
18 |
$ |
(72) |
|||||
EP ENERGY CORPORATION | |||||||||||
CONDENSED CONSOLIDATED BALANCE SHEETS | |||||||||||
(In millions) | |||||||||||
(Unaudited) | |||||||||||
June 30, 2018 |
March 31, 2018 |
December 31, 2017 | |||||||||
ASSETS |
|||||||||||
Current assets(1) |
$ |
329 |
$ |
237 |
$ |
466 |
|||||
Property, plant and equipment, net(2) |
4,832 |
4,741 |
4,422 |
||||||||
Other non-current assets |
13 |
11 |
12 |
||||||||
Total assets |
$ |
5,174 |
$ |
4,989 |
$ |
4,900 |
|||||
LIABILITIES AND EQUITY |
|||||||||||
Current liabilities |
$ |
479 |
$ |
436 |
$ |
448 |
|||||
Long-term debt, net of debt issue costs |
4,291 |
4,104 |
4,022 |
||||||||
Other non-current liabilities |
49 |
39 |
38 |
||||||||
Total stockholders' equity |
355 |
410 |
392 |
||||||||
Total liabilities and equity |
$ |
5,174 |
$ |
4,989 |
$ |
4,900 |
(1) |
Balance as of December 31, 2017 includes $172 million of assets held for sale. | |||||||
(2) |
Balance is net of accumulated depreciation, depletion and amortization of $3,424 million, $3,307 million and $3,179 million as of June 30, 2018, March 31, 2018 and December 31, 2017, respectively. |
EP ENERGY CORPORATION | |||||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS | |||||||
(In millions) | |||||||
(Unaudited) | |||||||
Six months ended June 30, | |||||||
2018 |
2017 | ||||||
Net loss |
$ |
(40) |
$ |
(50) |
|||
Adjustments to reconcile net loss to net cash provided by operating activities |
|||||||
Non-cash expenses |
214 |
305 |
|||||
Asset and liability changes |
43 |
(74) |
|||||
Net cash provided by operating activities |
217 |
181 |
|||||
Net cash used in investing activities |
(454) |
(266) |
|||||
Net cash provided by financing activities |
291 |
109 |
|||||
Change in cash, cash equivalents and restricted cash |
54 |
24 |
|||||
Cash, cash equivalents and restricted cash - beginning of period |
45 |
20 |
|||||
Cash, cash equivalents and restricted cash - end of period |
$ |
99 |
$ |
44 |
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment/modification of debt, impairment charges, other costs that affect comparability, including transition, severance and other costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net income (loss) per share to Adjusted EPS:
Quarter ended June 30, 2018 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(58) |
$ |
(0.23) | |||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
54 |
$ |
42 |
$ |
0.17 | |||||
Transition, severance and other costs |
6 |
5 |
0.02 | ||||||||
Gain on extinguishment/modification of debt |
(7) |
(5) |
(0.02) | ||||||||
Valuation allowance on deferred tax assets |
13 |
0.05 | |||||||||
Total adjustments |
$ |
53 |
$ |
55 |
$ |
0.22 | |||||
Adjusted EPS |
$ |
(0.01) | |||||||||
Diluted weighted average shares |
248 | ||||||||||
Quarter ended March 31, 2018 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net income |
$ |
18 |
$ |
0.07 | |||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
4 |
$ |
3 |
$ |
0.01 | |||||
Gain on extinguishment/modification of debt |
(41) |
(32) |
(0.13) | ||||||||
Valuation allowance on deferred tax assets |
(5) |
(0.02) | |||||||||
Total adjustments |
$ |
(37) |
$ |
(34) |
$ |
(0.14) | |||||
Adjusted EPS |
$ |
(0.07) | |||||||||
Diluted weighted average shares |
247 | ||||||||||
Quarter ended September 30, 2017 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(72) |
$ |
(0.29) | |||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
50 |
$ |
32 |
$ |
0.13 | |||||
Gain on extinguishment of debt |
(24) |
(15) |
(0.06) | ||||||||
Impairment charges |
1 |
— |
— | ||||||||
Valuation allowance on deferred tax assets |
24 |
0.10 | |||||||||
Total adjustments |
$ |
27 |
$ |
41 |
$ |
0.17 | |||||
Adjusted EPS |
$ |
(0.12) | |||||||||
Diluted weighted average shares |
246 |
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | ||||
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. | ||||
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, fees paid to the Sponsors, gains and losses on extinguishment/modification of debt and impairment charges.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter ended | |||||||||||||||
September 30, |
December 31, |
March 31, |
June 30, | ||||||||||||
2017 |
2018 | ||||||||||||||
($ in millions) | |||||||||||||||
Net (loss) income |
$ |
(72) |
(72) |
$ |
18 |
$ |
(58) |
||||||||
Income tax benefit |
(2) |
(2) |
— |
— |
|||||||||||
Interest expense, net of capitalized interest |
80 |
81 |
85 |
88 |
|||||||||||
Depreciation, depletion and amortization |
118 |
119 |
120 |
129 |
|||||||||||
Exploration expense |
3 |
2 |
1 |
1 |
|||||||||||
EBITDAX |
127 |
128 |
224 |
160 |
|||||||||||
Mark-to-market on financial derivatives(1) |
23 |
51 |
14 |
64 |
|||||||||||
Cash settlements and cash premiums on financial derivatives(2) |
27 |
7 |
(10) |
(10) |
|||||||||||
Non-cash portion of compensation expense(3) |
5 |
(29) |
2 |
2 |
|||||||||||
Transition, severance and other costs(4) |
— |
19 |
— |
6 |
|||||||||||
Fees paid to Sponsors(5) |
— |
5 |
— |
— |
|||||||||||
Gain on extinguishment/modification of debt |
(24) |
— |
(41) |
(7) |
|||||||||||
Impairment charges |
1 |
— |
— |
— |
|||||||||||
Adjusted EBITDAX |
$ |
159 |
181 |
$ |
189 |
$ |
215 |
(1) |
Represents the income statement impact of financial derivatives. | ||||
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | ||||
(3) |
Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. | ||||
(4) |
Reflects transition and severance costs related to workforce reductions. | ||||
(5) |
Represents fees paid in connection with the release of members of the new leadership team from a portfolio company of funds managed by Apollo Global Management LLC and payment of certain legal expenses. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, severance and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended | ||||||||||||||||||||||||
June 30, 2018 |
March 31, 2018 |
September 30, 2017 | ||||||||||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||||||||||
Oil and natural gas purchases |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
||||||||||||
Transportation costs |
26 |
3.49 |
25 |
3.43 |
29 |
3.91 |
||||||||||||||||||
Lease operating expense |
38 |
4.95 |
39 |
5.48 |
42 |
5.66 |
||||||||||||||||||
General and administrative |
28 |
3.74 |
19 |
2.58 |
25 |
3.28 |
||||||||||||||||||
Depreciation, depletion and amortization |
129 |
17.20 |
120 |
16.69 |
118 |
15.92 |
||||||||||||||||||
Impairment charges |
— |
— |
— |
— |
1 |
0.09 |
||||||||||||||||||
Exploration and other expense |
— |
— |
1 |
0.18 |
6 |
0.83 |
||||||||||||||||||
Taxes, other than income taxes |
21 |
2.82 |
20 |
2.75 |
16 |
2.10 |
||||||||||||||||||
Total operating expenses |
$ |
242 |
$ |
32.20 |
$ |
224 |
$ |
31.11 |
$ |
237 |
$ |
31.79 |
||||||||||||
Adjustments: |
||||||||||||||||||||||||
Depreciation, depletion and amortization |
$ |
(129) |
$ |
(17.20) |
$ |
(120) |
$ |
(16.69) |
$ |
(118) |
$ |
(15.92) |
||||||||||||
Impairment charges |
— |
— |
— |
— |
(1) |
(0.09) |
||||||||||||||||||
Exploration expense |
— |
— |
(1) |
(0.18) |
(3) |
(0.40) |
||||||||||||||||||
Non-cash portion of compensation expense(2) |
(2) |
(0.38) |
(2) |
(0.27) |
(5) |
(0.65) |
||||||||||||||||||
Transition, severance and other costs(2) |
(6) |
(0.77) |
— |
— |
— |
— |
||||||||||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
$ |
105 |
$ |
13.85 |
$ |
101 |
$ |
13.97 |
$ |
110 |
$ |
14.73 |
||||||||||||
Total consolidated equivalent volumes (MBoe) |
7,512 |
7,208 |
7,456 |
|||||||||||||||||||||
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. | |
(2) |
Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans and transition, severance and other costs.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense:
Actuals |
FY 2018 Estimate | ||||||||||||||||||||||||||||||
Quarter ended |
|||||||||||||||||||||||||||||||
June 30, |
March 31, |
September 30, |
Low |
High | |||||||||||||||||||||||||||
Total |
($/Boe) |
Total |
($/Boe) |
Total |
($/Boe) |
($/Boe) |
($/Boe) | ||||||||||||||||||||||||
($ in millions, except per Boe costs) | |||||||||||||||||||||||||||||||
GAAP general and administrative expense |
$ |
28 |
$ |
3.74 |
$ |
19 |
$ |
2.58 |
$ |
25 |
$ |
3.28 |
$ |
2.90 |
$ |
3.25 |
|||||||||||||||
Less non-cash compensation expense |
2 |
0.38 |
2 |
0.27 |
5 |
0.65 |
0.60 |
0.65 |
|||||||||||||||||||||||
Less transition, severance and other costs |
6 |
0.77 |
— |
— |
— |
— |
— |
— |
|||||||||||||||||||||||
Adjusted general and administrative expense |
$ |
20 |
$ |
2.59 |
$ |
17 |
$ |
2.31 |
$ |
20 |
$ |
2.63 |
$ |
2.30 |
$ |
2.60 |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
Net Debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents.
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative expense is used by management and investors as additional information. Net Debt is used by management for analysis of the company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative expense should not be used as an alternative to GAAP general and administrative expense. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and potential for sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of operating and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Jordan Strauss
713-997-6791
jordan.strauss@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reports-2q18-results---operating-and-financial-results-continue-to-demonstrate-strong-improvement-under-new-leadership-300695049.html
SOURCE EP Energy Corporation
HOUSTON, May 18, 2018 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), today announced the pricing of the previously announced unregistered offering of $1,000.0 million aggregate principal amount of 7.750% Senior Secured Notes due 2026 (the "Notes") at an issue price of 100%. The liens on the collateral securing the Notes will be junior to the liens on the collateral securing EP Energy's senior secured RBL facility and senior to the liens on the collateral securing each tranche of EP Energy's existing senior secured notes. The offering is expected to close on May 23, 2018, subject to certain closing conditions.
The Issuers intend to use the proceeds from the offering of the Notes, (i) to repay amounts outstanding under EP Energy's senior reserve based revolving credit facility, (ii) for other general corporate purposes and (iii) to pay related fees and expenses.
Additional Information
The Notes are being offered in a private offering that is exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), only to qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non‐U.S. investors pursuant to Regulation S. The Notes have not been registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from registration requirements or a transaction not subject to the registration requirements of the Securities Act or any state securities laws.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful.
About EP Energy LLC
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the company's ability to complete the offering of the Notes, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-announces-pricing-of-7-750-senior-secured-notes-due-2026--300651344.html
SOURCE EP Energy LLC
HOUSTON, May 8, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported first quarter 2018 financial and operational results.
Quickly Improving Operations and Results With New Leadership Team
In the first full quarter under new leadership, the company improved results by increasing production and profitability while significantly reducing costs. Below is a summary of first quarter 2018 results compared to third quarter 2017 results, which was the most recent full quarter under previous leadership.
3Q'17 |
1Q'18 |
Percent | |
Oil Production (MBbls/d) |
45.1 |
45.4 |
1% |
Lease Operating Expense ($MM) |
42 |
39 |
-7% |
Reported G&A ($MM) |
25 |
19 |
-24% |
Adjusted G&A ($MM)1 |
20 |
17 |
-15% |
Total Operating Expenses ($MM) |
237 |
224 |
-5% |
Adjusted Cash Operating Costs ($MM)1 |
110 |
101 |
-8% |
Net (Loss) Income ($MM) |
(72) |
18 |
|
Adjusted EBITDAX ($MM)1 |
159 |
189 |
+19% |
Permian Completed Well Cost ($MM)2 |
4.67 |
4.23 |
-9% |
1 See Disclosure of Non-GAAP Financial Measures for applicable definitions and reconciliations to GAAP terms. |
2 Comparison of wells completed in the Permian with similar proppant loading normalized to 7,500' |
Results Beat Expectations
First quarter 2018 total equivalent production and oil production volumes were above the high end of the company's guidance ranges, while capital expenditures were below the low end of the guidance range. The improvement was a result of better well performance driven by new completion techniques and lower capital and operating costs.
1Q'18 |
1Q'18 |
Delta to | |
Oil Production (MBbls/d) |
45.4 |
43 - 44 |
+ 4% |
Total Production (MBoe/d) |
80.1 |
77 - 79 |
+ 3% |
Oil and Gas Expenditures ($MM)1 |
208 |
210 - 220 |
- 3% |
1 Does not include acquisition costs |
Executing Strategy
Improved Flexibility
"We are pleased with our first quarter results and increased 1Q completion activity concentrated in the Eagle Ford," said Russell Parker, president and chief executive officer of EP Energy Corporation. "As we continue to focus on capital efficiency and fully loaded returns, we expect to continue to see improvements in the amount of capital deployed versus the amount of ultimate EBITDA generated. Additionally, we are swiftly moving forward with new projects in all three areas to unlock additional net asset value. Throughout the year we will continue to drive these initiatives in order to generate more shareholder value and improve the balance sheet."
Eagle Ford: Significant Increase in Oil Production
The company produced 35.9 MBoe/d, including 24.0 MBbls/d of oil in the first quarter of 2018, a 17 and 24 percent increase from the fourth quarter of 2017, respectively. The increase from year-end 2017 was driven by increased activity, improved production results from new well designs and completion techniques, and acquisition properties.
EP Energy averaged two drilling rigs, invested $135 million and completed (based on wells fracture stimulated or frac'd) 24 gross and net wells in the first quarter of 2018 in its Eagle Ford program. Activities and capital investment were up significantly from the fourth quarter of 2017 where total capital invested was $92 million and 14 wells were completed (frac'd). Approximately 75 percent of the 24 wells completed in the first quarter were in-fill wells and performance, on average, was equal to or in some cases better than, the parent well.
In addition to improving well performance, the company is driving down costs through on-site efficiency enhancement. EP Energy has taken over certain well-site operations from third parties. This has resulted in improved efficiencies and an overall savings of more than $100 thousand per well which the company expects to result in approximately $7 million of savings in 2018. This is an example of actions the new leadership team is quickly implementing which contribute to improved returns.
EP Energy launched its EOR pilot project with the first natural gas injection cycle in April. The project was the culmination of extensive research and study, which was done on an aggressive time frame and demonstrates the company's ability to quickly turn concepts into actionable opportunities. Facilities were in place and first gas was injected within four months of the initial concept review.
In April, the company amended its Permian drilling joint venture to direct the development area for the second tranche from the Permian to the Eagle Ford. The drilling joint venture improves the returns on the capital invested. The initial wells in the second tranche are expected to begin producing later this year. EP Energy remains the operator of the drilling joint venture and the material terms and conditions remain consistent with the initial agreement.
Permian: New Enhancements Increase Efficiencies and Reduce Operating Costs
In the first quarter of 2018, the company produced 27.0 MBoe/d, including 9.8 MBbls/d of oil, a 16 and 18 percent decrease compared to the fourth quarter of 2017, respectively. Production volumes were down compared to 2017 due to significantly lower activity levels in the fourth quarter of 2017 and first quarter of 2018. In the first quarter, the company averaged one drilling rig, invested $43 million in capital and completed (frac'd) eight gross and net wells.
During the quarter, the company began to use an electric-powered frac fleet, one of only a few operating in the country. The frac fleet utilizes field gas rather than diesel fuel to generate power, which saves costs and time. The company has increased average pumping hours per day by approximately 30 percent in its first three pads compared with the fourth quarter of 2017.
In the first quarter of 2018, the company began the installation of water handling facilities in the field, which are expected to provide significant operating efficiencies. The enhancements allow more water to be transmitted via pipeline, reducing truck traffic and operating costs. These cost saving initiatives, along with changes in managing drill-outs and flowback operations, are expected to result in more than $10 million of capital savings in 2018.
The company maintains ample take-away capacity out of the basin through contractual agreements with third-party processors and marketing companies. In addition, EP Energy has 100 percent of its Midland to Cushing basis exposure hedged in 2018 at -$1.02 per barrel.
Altamont: Accelerated Recompletions and Progress Towards Horizontal Drilling
In the first quarter of 2018, the company produced 17.2 MBoe/d, including 11.6 MBbls/d of oil, a four and five percent decrease from the fourth quarter of 2017, respectively.
EP Energy operated two joint venture drilling rigs and completed (frac'd) nine gross wells (three net wells) in its Altamont program. Total capital invested in the Altamont program in the first quarter of 2018 was $30 million. The company also accelerated its high return recompletion program, successfully recompleting 23 wells, an all-time record for the company.
The company began drilling its first horizontal wells in April, sooner than planned. The company spud two wells, expects to complete drilling operations in the second quarter and begin flowback in June/July.
Multi-year Commodity Hedge Program: Well Positioned in 2018 and ~26 Percent Hedged in 20191
EP Energy maintains a solid hedge program, which provides continued commodity price protection. A summary of the company's current open hedge positions is listed below:
2018 |
2019 | |||||||
Total Fixed Price Hedges |
||||||||
Oil volumes (MMBbls)2 |
11.3 |
4.6 |
||||||
Average ceiling price ($/Bbl) |
$ |
63.96 |
$ |
64.45 |
||||
Average floor price ($/Bbl) |
$ |
58.45 |
$ |
55.54 |
||||
Natural Gas volumes (TBtu) |
19.3 |
7.3 |
||||||
Average price ($/MMBtu) |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of May 4, 2018. | |
1 |
Percentage based on mid-point of 2018 production guidance |
2 |
2018 and 2019 positions include WTI three way collars of 6.7 MMBbls and 2.6 MMBbls, respectively, and WTI collars of 0.8 MMBbls in 2018 and 1.3 MMBbls in 2019. |
Liquidity
The company ended the quarter with approximately $600 million of available liquidity and $4.2 billion of net debt (total debt of $4.2 billion less cash of $19 million). EP Energy continues to be in active discussions with the banks in the RBL Facility to extend the maturity. The company continues to make progress and expects to complete the process in the second quarter of 2018.
2018 Outlook On Track With Strong Start
The table below summarizes the company's current operational and financial guidance for 2018. Included is the company's estimate for a significant increase in oil production volumes in the second quarter of 2018. Although full year 2018 production guidance remains as previously provided, the company will continue to review progress with the new operational techniques and provide updates throughout the year.
1Q'18 |
2Q'18 |
FY 2018 | |
Production Volumes |
|||
Oil production (MBbls/d) |
45.4 |
47 – 49 |
46 – 50 |
Total production (MBoe/d) |
80.1 |
80 – 82 |
81 – 87 |
Oil & Gas Expenditures ($ million) |
$208 |
$200 – $210 |
$600 – $6501 |
Eagle Ford |
$135 |
~50% | |
Permian |
$43 |
~30% | |
Altamont |
$30 |
~20%2 | |
Average Gross Drilling Rigs |
|||
Eagle Ford |
2 |
2 | |
Permian |
1 |
1 | |
Altamont |
2 |
2 | |
Operating Costs |
|||
Lease operating expense ($/Boe) |
$5.48 |
$5.00 – $5.70 | |
Reported G&A expense ($/Boe) |
$2.58 |
$2.90 – $3.25 | |
Adjusted G&A expense ($/Boe)3 |
$2.31 |
$2.30 – $2.60 | |
Transportation and commodity purchases ($/Boe) |
$3.43 |
$3.15 – $3.45 | |
Taxes, other than income ($/Boe)4 |
$2.75 |
$2.50 – $2.60 | |
DD&A ($/Boe) |
$16.69 |
$16.50 – $17.50 |
1 Full year 2018 includes ~$135 million non-drill capital including: ~$55 million for general equipment, ~$30 million for capitalized G&A and interest, ~$25 million for enhanced facility projects, ~$10 million for EOR projects, and ~$15 million for leasing and seismic, and does not include acquisition costs. |
2 Full year 2018 Altamont capital includes ~100 recompletions for $50 million. |
3 Adjusted G&A represents G&A expense less approximately $0.27 per Boe of non-cash compensation expense in 1Q'18 Actuals and $0.60 - $0.65 per Boe of non-cash compensation expense in FY 2018 Estimate. |
4 Severance taxes estimates are based on $55/Bbl WTI. |
Webcast Information
EP Energy has scheduled a webcast at 12:00 p.m. Eastern Time, 11:00 a.m. Central Time, on May 9, 2018, to discuss its first quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials relating to the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID#7126655) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through June 11, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID#10119858).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
The following table provides the company's production results, average realized prices, results of operations and certain non-GAAP financial measures for the periods presented.
Quarter ended March 31, |
Quarter ended | ||||||
2018 |
2017 |
2017 | |||||
Oil Sales Volumes (MBbls/d) |
|||||||
Eagle Ford |
24.0 |
23.9 |
20.0 | ||||
Permian |
9.8 |
11.1 |
12.6 | ||||
Altamont |
11.6 |
11.9 |
12.5 | ||||
Total Oil Sales Volumes |
45.4 |
46.9 |
45.1 | ||||
Natural Gas Sales Volumes (MMcf/d) |
|||||||
Eagle Ford |
36 |
41 |
37 | ||||
Permian |
56 |
54 |
55 | ||||
Altamont |
34 |
32 |
34 | ||||
Total Natural Gas Sales Volumes |
126 |
127 |
126 | ||||
NGLs Sales Volumes (MBbls/d) |
|||||||
Eagle Ford |
5.9 |
7.0 |
6.7 | ||||
Permian |
7.8 |
7.4 |
8.2 | ||||
Altamont |
— |
— |
— | ||||
Total NGLs Sales Volumes |
13.7 |
14.4 |
14.9 | ||||
Equivalent Sales Volumes (MBoe/d) |
|||||||
Eagle Ford |
35.9 |
37.7 |
32.9 | ||||
Permian |
27.0 |
27.5 |
29.9 | ||||
Altamont |
17.2 |
17.3 |
18.2 | ||||
Total Equivalent Sales Volumes |
80.1 |
82.5 |
81.0 | ||||
Net income (loss) ($ in millions) |
18 |
(47) |
(72) | ||||
Adjusted EBITDAX ($ in millions) |
189 |
172 |
159 | ||||
Basic and diluted net income (loss) per common share ($) |
0.07 |
(0.19) |
(0.29) | ||||
Adjusted EPS ($) |
(0.07) |
(0.10) |
(0.12) | ||||
Capital Expenditures ($ in millions)(1) |
208 |
152 |
162 | ||||
Total Operating Expenses ($/Boe) |
31.11 |
32.01 |
31.79 | ||||
Adjusted Cash Operating Costs ($/Boe) |
13.97 |
15.16 |
14.73 | ||||
Depreciation, depletion and amortization rate ($/Boe) |
16.69 |
16.99 |
15.92 | ||||
Average realized prices(2) |
|||||||
Oil price on physical sales ($/Bbl) |
61.56 |
48.43 |
45.49 | ||||
Oil, including financial derivatives ($/Bbl)(3) |
58.86 |
54.90 |
51.75 | ||||
Natural gas price on physical sales ($/Mcf) |
1.94 |
2.49 |
2.26 | ||||
Natural gas, including financial derivatives ($/Mcf)(3) |
2.03 |
2.46 |
2.49 | ||||
NGLs price on physical sales ($/Bbl) |
20.93 |
17.63 |
18.98 | ||||
NGLs, including financial derivatives ($Bbl)(3) |
20.91 |
17.76 |
18.45 |
_________________________________ | |
(1) |
The quarter ended March 31, 2018 does not include $248 million of acquisition capital. |
(2) |
Oil and natural gas prices on physical sales reflect operating revenues for oil and natural gas reduced by oil and natural gas purchases associated with managing our physical sales. |
(3) |
Prices per unit are calculated using total financial derivative cash settlements. |
EP ENERGY CORPORATION | ||||||||||
CONDENSED CONSOLIDATED STATEMENTS OF INCOME | ||||||||||
(In millions, except per common share amounts) | ||||||||||
(Unaudited) | ||||||||||
Quarter ended |
Quarter ended | |||||||||
2018 |
2017 |
2017 | ||||||||
Operating revenues |
||||||||||
Oil |
$ |
252 |
$ |
204 |
$ |
189 | ||||
Natural gas |
22 |
30 |
27 | |||||||
NGLs |
26 |
23 |
26 | |||||||
Financial derivatives |
(14) |
70 |
(23) | |||||||
Total operating revenues |
286 |
327 |
219 | |||||||
Operating expenses |
||||||||||
Oil and natural gas purchases |
— |
1 |
— | |||||||
Transportation costs |
25 |
29 |
29 | |||||||
Lease operating expense |
39 |
40 |
42 | |||||||
General and administrative |
19 |
20 |
25 | |||||||
Depreciation, depletion and amortization |
120 |
126 |
118 | |||||||
Impairment charges |
— |
— |
1 | |||||||
Exploration and other expense |
1 |
3 |
6 | |||||||
Taxes, other than income taxes |
20 |
19 |
16 | |||||||
Total operating expenses |
224 |
238 |
237 | |||||||
Operating income (loss) |
62 |
89 |
(18) | |||||||
Gain (loss) on extinguishment/modification of debt |
41 |
(53) |
24 | |||||||
Interest expense |
(85) |
(83) |
(80) | |||||||
Income (loss) before income taxes |
18 |
(47) |
(74) | |||||||
Income tax expense |
— |
— |
2 | |||||||
Net income (loss) |
$ |
18 |
$ |
(47) |
$ |
(72) |
EP ENERGY CORPORATION | |||||||
CONDENSED CONSOLIDATED BALANCE SHEETS | |||||||
(In millions) | |||||||
(Unaudited) | |||||||
March 31, 2018 |
December 31, 2017 | ||||||
ASSETS |
|||||||
Current assets(1) |
$ |
237 |
$ |
466 |
|||
Property, plant and equipment, net(2) |
4,741 |
4,422 |
|||||
Other non-current assets |
11 |
12 |
|||||
Total assets |
$ |
4,989 |
$ |
4,900 |
|||
LIABILITIES AND EQUITY |
|||||||
Current liabilities |
$ |
436 |
$ |
448 |
|||
Long-term debt, net of debt issue costs |
4,104 |
4,022 |
|||||
Other non-current liabilities |
39 |
38 |
|||||
Total stockholders' equity |
410 |
392 |
|||||
Total liabilities and equity |
$ |
4,989 |
$ |
4,900 |
______________________________ | |
(1) |
Balance as of December 31, 2017 includes $172 million of assets held for sale. |
(2) |
Balance is net of accumulated depreciation, depletion and amortization of $3,307 million and $3,179 million as of March 31, 2018 and December 31, 2017, respectively. |
EP ENERGY CORPORATION | |||||||
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS | |||||||
(In millions) | |||||||
(Unaudited) | |||||||
Three months ended March 31, | |||||||
2018 |
2017 | ||||||
Net income (loss) |
$ |
18 |
$ |
(47) |
|||
Adjustments to reconcile net income (loss) to net cash provided by operating activities |
|||||||
Non-cash expenses |
84 |
184 |
|||||
Asset and liability changes |
(15) |
(20) |
|||||
Net cash provided by operating activities |
87 |
117 |
|||||
Net cash used in investing activities |
(229) |
(119) |
|||||
Net cash provided by financing activities |
117 |
17 |
|||||
Change in cash, cash equivalents and restricted cash |
(25) |
15 |
|||||
Cash, cash equivalents and restricted cash - beginning of period |
45 |
20 |
|||||
Cash, cash equivalents and restricted cash - end of period |
$ |
20 |
$ |
35 |
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Below is a reconciliation of consolidated diluted net income (loss) per share to Adjusted EPS:
Quarter ended March 31, 2018 | |||||||||||
Pre Tax |
After Tax |
Diluted | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net income |
$ |
18 |
$ |
0.07 |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
4 |
$ |
3 |
$ |
0.01 |
|||||
Gain on extinguishment/modification of debt |
(41) |
(32) |
(0.13) |
||||||||
Valuation allowance on deferred tax assets |
(5) |
(0.02) |
|||||||||
Total adjustments |
$ |
(37) |
$ |
(34) |
$ |
(0.14) |
|||||
Adjusted EPS |
$ |
(0.07) |
|||||||||
Diluted weighted average shares |
247 |
||||||||||
Quarter ended March 31, 2017 | |||||||||||
Pre Tax |
After Tax |
Diluted | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(47) |
$ |
(0.19) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
(42) |
$ |
(27) |
$ |
(0.11) |
|||||
Loss on extinguishment of debt |
53 |
34 |
0.14 |
||||||||
Valuation allowance on deferred tax assets |
15 |
0.06 |
|||||||||
Total adjustments |
$ |
11 |
$ |
22 |
$ |
0.09 |
|||||
Adjusted EPS |
$ |
(0.10) |
|||||||||
Diluted weighted average shares |
245 |
||||||||||
Quarter ended September 30, 2017 | |||||||||||
Pre Tax |
After Tax |
Diluted | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(72) |
$ |
(0.29) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
50 |
$ |
32 |
$ |
0.13 |
|||||
Loss on extinguishment of debt |
(24) |
(15) |
(0.06) |
||||||||
Impairment charges |
1 |
— |
— |
||||||||
Valuation allowance on deferred tax assets |
24 |
0.10 |
|||||||||
Total adjustments |
$ |
27 |
$ |
41 |
$ |
0.17 |
|||||
Adjusted EPS |
$ |
(0.12) |
|||||||||
Diluted weighted average shares |
246 |
________________________________ | |
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. |
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the period presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), gains on extinguishment/modification of debt and impairment charges.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter |
Quarter | ||||||
2018 |
2017 | ||||||
($ in millions) | |||||||
Net income (loss) |
$ |
18 |
$ |
(72) |
|||
Income tax expense |
— |
(2) |
|||||
Interest expense, net of capitalized interest |
85 |
80 |
|||||
Depreciation, depletion and amortization |
120 |
118 |
|||||
Exploration expense |
1 |
3 |
|||||
EBITDAX |
224 |
127 |
|||||
Mark-to-market on financial derivatives(1) |
14 |
23 |
|||||
Cash settlements and cash premiums on financial derivatives(2) |
(10) |
27 |
|||||
Non-cash portion of compensation expense(3) |
2 |
5 |
|||||
Gain on extinguishment/modification of debt |
(41) |
(24) |
|||||
Impairment charges |
— |
1 |
|||||
Adjusted EBITDAX |
$ |
189 |
$ |
159 |
________________________________ | |
(1) |
Represents the income statement impact of financial derivatives. |
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(3) |
Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges and the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans). We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. We exclude the non-cash portion of compensation expense, as we believe such adjustment allows investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended |
Quarter ended | ||||||||||||||
2018 |
2017 | ||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | ||||||||||||
($ in millions, except per unit costs) | |||||||||||||||
Oil and natural gas purchases |
$ |
— |
$ |
— |
$ |
— |
$ |
— |
|||||||
Transportation costs |
25 |
3.43 |
29 |
3.91 |
|||||||||||
Lease operating expense |
39 |
5.48 |
42 |
5.66 |
|||||||||||
General and administrative |
19 |
2.58 |
25 |
3.28 |
|||||||||||
Depreciation, depletion and amortization |
120 |
16.69 |
118 |
15.92 |
|||||||||||
Impairment charges |
— |
— |
1 |
0.09 |
|||||||||||
Exploration and other expense |
1 |
0.18 |
6 |
0.83 |
|||||||||||
Taxes, other than income taxes |
20 |
2.75 |
16 |
2.10 |
|||||||||||
Total operating expenses |
$ |
224 |
$ |
31.11 |
$ |
237 |
$ |
31.79 |
|||||||
Adjustments: |
|||||||||||||||
Depreciation, depletion and amortization |
$ |
(120) |
$ |
(16.69) |
$ |
(118) |
$ |
(15.92) |
|||||||
Impairment charges |
— |
— |
(1) |
(0.09) |
|||||||||||
Exploration expense |
(1) |
(0.18) |
(3) |
(0.40) |
|||||||||||
Non-cash portion of compensation expense(2) |
(2) |
(0.27) |
(5) |
(0.65) |
|||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
$ |
101 |
$ |
13.97 |
$ |
110 |
$ |
14.73 |
|||||||
Total consolidated equivalent volumes (MBoe) |
7,208 |
7,456 |
______________________________ | |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
(2) |
Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense:
Actuals |
|||||||||||||||||||
As of March 31, |
As of September 30, |
FY 2018 Estimate | |||||||||||||||||
2018 |
2017 |
Low |
High | ||||||||||||||||
Total |
($/Boe) |
Total |
($/Boe) |
($/Boe) |
($/Boe) | ||||||||||||||
($ in millions, except per Boe costs) |
|||||||||||||||||||
GAAP general and administrative expense |
$ |
19 |
$ |
2.58 |
$ |
25 |
$ |
3.28 |
$ |
2.90 |
$ |
3.25 |
|||||||
Less non-cash compensation expense |
2 |
0.27 |
5 |
0.65 |
0.60 |
0.65 |
|||||||||||||
Adjusted general and administrative expense |
$ |
17 |
$ |
2.31 |
$ |
20 |
$ |
2.63 |
$ |
2.30 |
$ |
2.60 |
______________________________ | |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
Net Debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents.
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative expense is used by management and investors as additional information. Net Debt is used by management for analysis of the Company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative expense should not be used as an alternative to GAAP general and administrative expense. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted Cash Operating Costs, Adjusted General and Administrative expense and Net Debt should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reports-1q18-results-which-beat-production-and-capital-guidance----guides-production-rate-up-and-capital-spend-down-for-2q18-300644874.html
SOURCE EP Energy Corporation
HOUSTON, May 7, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at noon Eastern Time, 11 a.m. Central Time, on Wednesday, May 9 to discuss its first quarter 2018 financial and operational results. The company's first quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Tuesday, May 8, 2018.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 7126655) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through June 11, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10119858). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-to-host-first-quarter-results-webcast-on-may-9-300643998.html
SOURCE EP Energy Corporation
HOUSTON, Feb. 28, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported fourth quarter and year-end 2017 financial and operational results for the company.
Key highlights include:
2017 Full Year Results
2017 Proved Reserves
"We have been making meaningful progress on multiple fronts since coming on board in November last year," said Russell Parker, president and chief executive officer of EP Energy Corporation. "The organization has been restructured to increase the speed of execution and decision making. In each operating area we are blending in new concepts to improve asset performance, increase capital efficiency and reduce operating costs. So far in 2018, we have improved our financial flexibility by extending $1.2 billion of near term maturities, and we enhanced our portfolio of capital efficient projects with the completion of two successful A&D transactions. We are pleased with our progress so far, but we are even more excited about executing on the opportunities ahead that will drive us toward cash flow neutrality and reduced leverage."
2017 Financial Results
Fourth Quarter 2017
For the quarter ended December 31, 2017, EP Energy reported a $0.29 diluted net loss per share and $0.07 adjusted loss per share. The reported net loss for the fourth quarter of 2017 was $72 million, versus a $140 million net loss in the same 2016 period, due to higher realized pricing on oil and NGL volumes and lower reported general and administrative costs. Adjusted EBITDAX for the fourth quarter 2017 was $181 million, down from $255 million in the fourth quarter of 2016, due to $118 million less of hedge settlements and lower total equivalent and oil volumes in 2017 versus 2016, partially offset by higher realized pricing on physical sales.
The company ended the year with fourth quarter operating expenses of $217 million, down from $247 million in the fourth quarter of 2016 due to lower reported general and administrative costs. Adjusted cash operating costs were $101 million for the fourth quarter 2017, down from $111 million in the same 2016 period. Adjusted cash operating costs were $13.65 per barrel of oil equivalent (Boe) for the fourth quarter 2017, down from $14.80 per Boe in the same 2016 period mainly due to lower adjusted general and administrative costs, partially offset by higher production taxes from higher pricing in 2017.
Capital expenditures in the fourth quarter 2017 were $145 million, up from $116 million in the same period 2016, due to increased drilling activity in the Eagle Ford in 2017. The company spent $92 million in the Eagle Ford, $28 million in the Permian and $25 million in the Altamont. In the fourth quarter 2017, the company completed 30 gross wells, 14 of which were in the Eagle Ford, seven in the Permian as part of the company's drilling joint venture and nine in the Altamont drilling joint venture.
Full Year 2017
For the year ended December 31, 2017, EP Energy reported $0.79 diluted net loss per share and $0.39 adjusted loss per share. Reported net loss was $194 million for the year 2017, compared to a $27 million net loss in the same 2016 period, which included approximately $450 million of gains on extinguishment of debt and asset sales in 2016. Adjusted EBITDAX for the year 2017 was $691 million, down from $1,039 million in 2016 due primarily to $546 million in lower hedge settlements offset by higher realized pricing on oil and NGL volumes in 2017.
Total operating expenses for the year ended December 31, 2017 were $927 million, up from $865 million in the same 2016 period. The difference was driven by a $78 million gain on the sale of the Haynesville assets in 2016. Adjusted cash operating costs were $427 million for the year 2017, down from $440 million in the same 2016 period. Adjusted cash operating costs per unit were $14.23 per Boe for the year 2017, up slightly from $13.77 per Boe in the same 2016 period due to lower volumes and higher production taxes resulting from higher pricing in 2017.
Capital expenditures in 2017 were $587 million, up from $488 million in the same period 2016. In 2017, the company spent $227 million in the Eagle Ford, $267 million in the Permian (including $29 million of acquisitions) and $93 million in the Altamont. In 2017, the company completed 149 gross wells, which was approximately 50 more than EP Energy completed in 2016. In 2017, the company completed 53 wells in the Eagle Ford, 71 wells in the Permian, including 58 wells in the drilling joint venture and 25 wells in the Altamont.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Financial Position and Liquidity
At December 31, 2017, EP Energy's balance sheet included $4.1 billion of total debt and approximately $27 million of cash and cash equivalents.
In January 2018, EP Energy successfully exchanged and extended the maturity on approximately $1.1 billion of senior unsecured notes maturing in 2020, 2022 and 2023 for new senior secured notes maturing in 2024. The company has no significant near-term debt maturities with the Reserve-Based Loan Facility (RBL Facility) maturing in May 2019 and a manageable level of approximately $275 million in maturities over the next four years. The company plans to address the extension of the RBL Facility by the end of the second quarter 2018.
As of December 31, 2017, the company had approximately $800 million of total liquidity. Pro-forma for the January 2018 debt exchange, the company had approximately $700 million of liquidity at year-end 2017. The company remains focused on balance sheet improvement and maintaining strong financial flexibility. The company expects to reduce its net debt to adjusted EBITDAX ratio in 2018.
Operations
For the year ended December 31, 2017, average daily production was 82.3 MBoe/d, including 46.1 MBbls/d of oil. Fourth quarter 2017 average daily production was 80.6 MBoe/d, including 43.6 MBbls/d of oil. The decrease in the third and fourth quarter production is due to the timing of Eagle Ford activity that was focused early in 2017.
Eagle Ford Program
In 2017, the company completed 53 wells in its Eagle Ford program and production was 35.7 MBoe/d, an 18 percent decrease from 2016 due to reduced capital spending since 2015. During the fourth quarter of 2017, the company completed 14 wells and produced 30.6 MBoe/d, a 19 percent decrease from the fourth quarter of 2016. In 2018, the company expects to significantly increase year over year annual production for the first time since 2015.
EP Energy expanded its Eagle Ford horizontal shale inventory by approximately 200 future drilling locations with the acquisition of producing properties and undeveloped acreage from Carrizo Oil & Gas, Inc., which closed in January 2018.
In the Eagle Ford, the company has increased the current oil field production rate by 20 percent compared with the fourth quarter 2017 average. Half of the increase was driven by performance from new wells and half of the increase was due to the acquisition. Included in these results are four Ritchie Farms in-fill pad child wells that have been on-line for 25 days with cumulative production six percent higher than the parent well. The company also completed four new Volatile Oil wells in December and January that had a 60-day oil rate 30 percent higher than the company's type curve.
EP Energy continues to test initiatives for optimal field development and well design to increase production rates, cash flow and asset value.
Permian Program
In 2017, the company completed 71 wells in its Permian program and produced 28.7 MBoe/d, a 34 percent increase from 2016. In the fourth quarter of 2017, the company completed seven wells, down from 21 completed wells in the same 2016 period, and produced 32.1 MBoe/d, a 17 percent increase from the fourth quarter of 2016.
Also in 2017, EP Energy completed several bolt-on acquisitions in Upton County which added current production and future drilling locations. These acquisitions totaled approximately $29 million and included approximately 3,600 net acres in Upton County with gross oil production of 300 Bbls/d. The transactions added approximately 60 future drilling locations and enabled the company to extend approximately 20 short lateral locations to long lateral locations.
In the Permian, the company is focused on reducing operating costs with enhanced water handling facilities, further optimizing its development program and maintaining its drilling commitments for 2018.
Altamont Program
The company continued to efficiently develop its Altamont program, with the highest returns achieved in its recompletion program. In 2017, the company completed 25 wells and performed 59 recompletions. The company benefits from a significant inventory of recompletion opportunities, which generate some of the highest project returns in the portfolio.
Full year production was 17.9 MBoe/d, eight percent higher than 2016 driven by improved performance and higher activity levels of the company's drilling and recompletion programs. In the fourth quarter 2017, the company completed nine wells and had production volumes of 17.9 MBoe/d.
During the year, the company benefited from improved realized pricing relative to WTI oil prices and higher returns with its drilling joint venture.
Hedge Program Update
In 2017, EP Energy realized $93 million from settlements on financial derivatives. At year-end 2017, the mark-to-market value of the company's hedge positions was approximately $5 million. For 2018, EP Energy has effectively hedged approximately 89 percent of its expected oil production at an average price of $58.47 per barrel, and hedged approximately 56 percent of its expected natural gas production at an average price of $3.04 per MMBtu. Importantly, the company also has the ability to participate in upside pricing movements on two-thirds of its anticipated 2018 production as a result of having a collar structure on a portion of its derivatives.
A summary of the company's 2018 and 2019 hedge positions is listed below:
2018 |
2019 | ||||||
Total Fixed Price Hedges |
|||||||
Oil volumes (MMBbls) |
14.9 |
1.8 |
|||||
Average floor price ($/Bbl) |
$ |
58.47 |
$ |
55.35 |
|||
Natural gas volumes (TBtu) |
25.6 |
7.3 |
|||||
Average floor prices ($/MMBtu) |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of January 31, 2018 (Contract months: January 2018 - Forward) and the table includes WTI three-way collars of 8.9 MMBbls and 1.1 MMBbls in 2018 and 2019, respectively, and WTI collars of 1.0 MMBbls in 2018. |
2017 Proved Reserves
EP Energy's proved oil and natural gas reserves were 392.1 MMBoe as of December 31, 2017, a nine percent decrease compared to proved reserves at December 31, 2016 of 432.4 MMBoe. Proved developed reserves increased seven percent from 204.6 MMBoe in 2016 to 218.3 MMBoe in 2017. In 2017, proved developed reserves were 56 percent of total proved reserves and 52 percent oil.
2017 proved reserves were lower than 2016 primarily due to divestitures relating to the company's two drilling joint ventures and ownership changes, resulting from higher WTI prices under the variable royalty rates agreement with University Lands. Excluding the impact of the divestitures and ownership changes 2017 proved reserves were essentially flat to 2016. Importantly, proved developed reserves increased to 56 percent of the company's total reserves, up from 47 percent in 2016.
The SEC first-day-of-the-month 12-month average prices for reserves as of December 31, 2017 were $51.34 per Bbl for oil and $2.98 per MMBtu for natural gas, up from $42.75 per Bbl for oil and $2.48 per MMBtu for natural gas in the prior 12-month period.
2018 Outlook
EP Energy is reaffirming its previously provided operational and financial guidance for full year 2018. In addition, the company is providing production and capital guidance for the first quarter of 2018.
1Q'18 |
2018 | ||
Oil production (MBbls/d) |
43 - 44 |
46 - 50 | |
Total production (MBoe/d) |
77 - 79 |
81 - 87 | |
Oil & Gas Expenditures ($ million)1,2 |
$210 - $220 |
$600 - $650 | |
Eagle Ford |
~50% | ||
Permian |
~30% | ||
Altamont |
~20% | ||
Average gross drilling rigs |
|||
Eagle Ford |
1 - 2 | ||
Permian |
1 | ||
Altamont |
2 | ||
Operating Costs |
|||
Lease operating expense ($/Boe) |
$5.00 - $5.70 | ||
G&A expense ($/Boe) |
$2.90 - $3.25 | ||
Adjusted G&A expense ($/Boe)3 |
$2.30 - $2.60 | ||
Transportation and commodity purchases ($/Boe) |
$3.15 - $3.45 | ||
Taxes, other than income ($/Boe)4 |
$2.50 - $2.60 | ||
DD&A ($/Boe) |
$16.50 - $17.50 | ||
1 Includes ~$135 million non-drill capital including; ~$55 million for general equipment, ~$30 million for capitalized G&A and interest, ~$25 million for enhanced facility projects, ~$10 million for enhanced oil recovery projects, and ~$15 million for leasing and seismic, and excludes net acquisition costs and divestiture proceeds of ~$57 million. |
2 Altamont capital includes ~100 recompletions for $50 million. |
3 Adjusted G&A represents G&A expense less approximately $0.60 - $0.65 per Boe of non-cash compensation expense. |
4 Severance taxes are based on $55/Bbl WTI. |
Webcast Information
EP Energy has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on March 1, to discuss its fourth quarter and full year financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 1387932) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through April 5, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10117505).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, fees paid to the Sponsors, gains and losses on extinguishment of debt, gains and/or losses on sale of assets and impairment charges. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net loss to EBITDAX and Adjusted EBITDAX:
Quarter ended December 31, |
Year ended December 31, | ||||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||||
($ in millions, except equivalent volumes and per unit) | |||||||||||||||
Net loss |
$ |
(72) |
$ |
(140) |
$ |
(194) |
$ |
(27) |
|||||||
Income tax (benefit) expense |
(2) |
— |
(9) |
1 |
|||||||||||
Interest expense, net of capitalized interest |
81 |
81 |
326 |
312 |
|||||||||||
Depreciation, depletion and amortization |
119 |
120 |
487 |
462 |
|||||||||||
Exploration expense |
2 |
2 |
9 |
5 |
|||||||||||
EBITDAX |
128 |
63 |
619 |
753 |
|||||||||||
Mark-to-market on financial derivatives(1) |
51 |
53 |
(41) |
73 |
|||||||||||
Cash settlements and cash premiums on financial derivatives(2) |
7 |
125 |
93 |
639 |
|||||||||||
Non-cash portion of compensation expense(3) |
(29) |
7 |
(22) |
19 |
|||||||||||
Transition, severance and other costs(4) |
19 |
5 |
19 |
15 |
|||||||||||
Fees paid to Sponsors(5) |
5 |
— |
5 |
— |
|||||||||||
Gain on sale of assets |
— |
— |
— |
(78) |
|||||||||||
Loss (gain) on extinguishment of debt |
— |
— |
16 |
(384) |
|||||||||||
Impairment charges |
— |
2 |
2 |
2 |
|||||||||||
Adjusted EBITDAX |
$ |
181 |
$ |
255 |
$ |
691 |
$ |
1,039 |
|||||||
Total equivalent volumes (MBoe) |
7,412 |
7,594 |
30,024 |
32,077 |
|||||||||||
Adjusted EBITDAX Per Unit (MBoe)(6) |
$ |
24.43 |
$ |
33.53 |
$ |
23.03 |
$ |
32.39 |
(1) |
Represents the income statement impact of financial derivatives. | |||||
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | |||||
(3) |
Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments made under these plans. | |||||
(4) |
Reflects transition and severance costs related to workforce reductions. | |||||
(5) |
Represents fees paid in connection with the release of members of the new leadership team from a portfolio company of funds managed by Apollo Global Management LLC and payment of certain legal expenses. | |||||
(6) |
Adjusted EBITDAX Per Unit is based on actual amounts rather than the rounded totals presented. |
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the Company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment of debt, gains and/or losses on sale of assets, impairment charges, other costs that affect comparability, including transition, severance and other costs and associated LTI forfeitures, fees paid to the Sponsors and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS:
Quarter ended December 31, 2017 | |||||||||||
Pre-Tax |
After-Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(72) |
$ |
(0.29) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
58 |
$ |
37 |
$ |
0.15 |
|||||
Transition, severance and other costs |
|||||||||||
Severance and other costs(4) |
19 |
12 |
$ |
0.05 |
|||||||
Fees paid to Sponsors(5) |
5 |
3 |
$ |
0.01 |
|||||||
Long-term incentive forfeitures |
(33) |
(31) |
$ |
(0.13) |
|||||||
Valuation allowance on deferred tax assets |
33 |
0.14 |
|||||||||
Total adjustments |
$ |
49 |
$ |
54 |
$ |
0.22 |
|||||
Adjusted EPS |
$ |
(0.07) |
|||||||||
Diluted weighted average shares(6) |
246 |
Year ended December 31, 2017 | |||||||||||
Pre-Tax |
After-Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(194) |
$ |
(0.79) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
52 |
$ |
33 |
$ |
0.14 |
|||||
Transition, severance and other costs |
|||||||||||
Severance and other costs(4) |
19 |
12 |
0.05 |
||||||||
Fees paid to Sponsors(5) |
5 |
3 |
0.01 |
||||||||
Long-term incentive forfeitures |
(33) |
(31) |
(0.13) |
||||||||
Loss on extinguishment/modification of debt |
16 |
11 |
0.04 |
||||||||
Impairment charges |
2 |
— |
— |
||||||||
Valuation allowance on deferred tax assets |
69 |
$ |
0.29 |
||||||||
Total adjustments |
$ |
61 |
$ |
97 |
$ |
0.40 |
|||||
Adjusted EPS |
$ |
(0.39) |
|||||||||
Diluted weighted average shares(6) |
246 |
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | |||||
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate of approximately 36%, as well as any other income tax effects specifically attributable to that item. Taxes associated with certain LTI forfeitures related to the change in management are generally not deductible for tax purposes. | |||||
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. | |||||
(4) |
Reflects transition and severance costs related to workforce reductions. | |||||
(5) |
Represents fees paid in connection with the release of members of the new leadership team from a portfolio company of funds managed by Apollo Global Management LLC and payment of certain legal expenses. | |||||
(6) |
Diluted shares include certain restricted stock and performance unit awards. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense (net of forfeitures) under our long-term incentive programs adjusted for cash payments under these plans, transition, severance and other costs and fees paid to the Sponsors.
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains and/or losses on sales of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability and fees paid to the Sponsors. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to the operation of our assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability and fees paid to the Sponsors, as we believe such adjustments allow investors to evaluate our costs against others in our industry and these items can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter Ended December 31, | ||||||||||||||||
2017 |
2016 | |||||||||||||||
Total |
Per Unit |
Total |
Per Unit | |||||||||||||
Oil and natural gas purchases |
$ |
— |
$ |
— |
$ |
1 |
$ |
0.17 |
||||||||
Transportation costs |
29 |
3.92 |
28 |
3.71 |
||||||||||||
Lease operating expense |
42 |
5.60 |
42 |
5.59 |
||||||||||||
General and administrative |
10 |
1.35 |
45 |
5.85 |
||||||||||||
Depreciation, depletion and amortization |
119 |
16.01 |
120 |
15.78 |
||||||||||||
Impairment charges |
— |
— |
2 |
0.21 |
||||||||||||
Exploration and other expense |
2 |
0.20 |
2 |
0.23 |
||||||||||||
Taxes, other than income taxes |
15 |
2.08 |
7 |
1.08 |
||||||||||||
Total operating expenses |
$ |
217 |
$ |
29.16 |
$ |
247 |
$ |
32.62 |
||||||||
Adjustments: |
||||||||||||||||
Depreciation, depletion and amortization |
$ |
(119) |
$ |
(16.01) |
$ |
(120) |
$ |
(15.78) |
||||||||
Impairment charges |
— |
— |
(2) |
(0.21) |
||||||||||||
Exploration expense |
(2) |
(0.20) |
(2) |
(0.23) |
||||||||||||
Non-cash portion of compensation expense(2) |
29 |
3.95 |
(7) |
(0.89) |
||||||||||||
Transition, severance and other costs(2) |
(19) |
(2.56) |
(5) |
(0.71) |
||||||||||||
Fees paid to Sponsors(2) |
(5) |
(0.69) |
— |
— |
||||||||||||
Adjusted cash operating costs and per unit adjusted cash costs |
$ |
101 |
$ |
13.65 |
$ |
111 |
$ |
14.80 |
||||||||
Total consolidated equivalent volumes (MBoe) |
7,412 |
7,594 |
Year Ended December 31, | ||||||||||||||||
2017 |
2016 | |||||||||||||||
Total |
Per-Unit |
Total |
Per-Unit | |||||||||||||
Oil and natural gas purchases |
$ |
2 |
$ |
0.07 |
$ |
10 |
$ |
0.32 |
||||||||
Transportation costs |
115 |
3.83 |
109 |
3.41 |
||||||||||||
Lease operating expense |
163 |
5.42 |
159 |
4.97 |
||||||||||||
General and administrative |
81 |
2.69 |
146 |
4.54 |
||||||||||||
Depreciation, depletion and amortization |
487 |
16.22 |
462 |
14.40 |
||||||||||||
Gain on sale of assets |
— |
— |
(78) |
(2.44) |
||||||||||||
Impairment charges |
2 |
0.04 |
2 |
0.05 |
||||||||||||
Exploration and other expense |
12 |
0.40 |
5 |
0.16 |
||||||||||||
Taxes, other than income taxes |
65 |
2.19 |
50 |
1.58 |
||||||||||||
Total operating expenses |
$ |
927 |
$ |
30.86 |
$ |
865 |
$ |
26.99 |
||||||||
Adjustments: |
||||||||||||||||
Depreciation, depletion and amortization |
$ |
(487) |
$ |
(16.22) |
$ |
(462) |
$ |
(14.40) |
||||||||
Impairment charges |
(2) |
(0.04) |
(2) |
(0.05) |
||||||||||||
Gain on sale of assets |
— |
— |
78 |
2.44 |
||||||||||||
Exploration expense |
(9) |
(0.30) |
(5) |
(0.16) |
||||||||||||
Non-cash portion of compensation expense(2) |
22 |
0.75 |
(19) |
(0.58) |
||||||||||||
Transition, restructuring and other costs(2) |
(19) |
(0.64) |
(15) |
(0.47) |
||||||||||||
Fees paid to Sponsors(2) |
(5) |
(0.18) |
— |
— |
||||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
$ |
427 |
$ |
14.23 |
$ |
440 |
$ |
13.77 |
||||||||
Total consolidated equivalent volumes (MBoe) |
30,024 |
32,077 |
(1) |
Per unit costs are based on actual amounts rather than the rounded totals presented. | |||||
(2) |
Amounts are excluded in the calculation of adjusted general and administrative expense. |
EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted General and Administrative Expense is used by management and investors as additional information. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted General and Administrative Expense and Adjusted Cash Operating Costs have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted General and Administrative Expense should not be used as an alternative to GAAP general and administrative expense. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted General and Administrative Expense and Adjusted Cash Operating Costs may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted General and Administrative Expense and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-announces-fourth-quarter-and-full-year-2017-results-300606187.html
SOURCE EP Energy Corporation
HOUSTON, Feb. 26, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Thursday, March 1, to discuss its fourth quarter and full year 2017 financial and operational results. The company's fourth quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, February 28, 2018.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 1387932) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through April 5, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10117505). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-to-host-fourth-quarter-and-full-year-2017-results-webcast-on-march-1-300604257.html
SOURCE EP Energy Corporation
HOUSTON, Feb. 9, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today announced that it has closed the previously announced acquisition of certain producing properties and undeveloped acreage in the Eagle Ford operating area in South Texas. The company also closed on the previously announced divestiture of certain assets in its Altamont acreage in the Uinta Basin.
The aggregate cash paid for the acquired properties was approximately $245 million, subject to post-closing adjustments, while the divested properties generated estimated proceeds of approximately $180 million, also subject to post-closing adjustments.
"We are pleased to deliver on an early achievement for the company under the new leadership team," said Russell Parker, president and chief executive officer of EP Energy Corporation. "The acquisition is the largest to date for the company, and we were able to complete the transactions in a balance sheet friendly manner bringing forward value from the divestiture. We are also pleased that our team has already integrated the newly acquired assets into our operations. We now look to further optimize these assets and grow production."
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas, and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Jan. 29, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) announced it has added two key members to its board of directors filling the open independent director seats.
Mr. Robert "Bob" C. Reeves was elected to EP Energy's board of directors as an independent director in December 2017. Mr. Reeves was Athlon Energy's Chairman, President and Chief Executive Officer from its formation in 2010 until its sale to Encana Corporation in 2014, and helped to build the company into a premier independent oil and gas firm. Prior to that time, he was Senior Vice President, Chief Financial Officer and Treasurer of Encore Acquisition Company and Encore Energy Partners. Mr. Reeves has served on the board of directors for privately held Incline Niobrara Partners LP since its formation in 2015. Mr. Reeves is a graduate of the University of Kansas with a Bachelor of Science degree in Accounting. He is a member of the company's Audit Committee and Governance & Nominating Committee.
Mr. J. Barton "Bart" Kalsu was elected to EP Energy's board of directors as an independent director, effective immediately. Mr. Kalsu brings successful financial leadership to the board with more than 25 years of experience in global finance and accounting roles. He is currently Executive Vice President and Chief Financial Officer for SolarWinds, Inc. He joined SolarWinds, Inc. in 2007 as Chief Accountant and Vice President, Finance. Mr. Kalsu previously served on the board of directors of Athlon Energy prior to its acquisition by Encana Corporation in 2014. Mr. Kalsu is a graduate of Oklahoma State University with a Bachelor of Science degree in Accounting. He will serve as Chairman of the Audit Committee and as a member of the Compensation Committee.
"Everyone on the board is pleased with the additional insight and energy both Bob and Bart bring to the company," said Alan Crain, Chairman of EP Energy Corporation. "Bob has had outstanding success building and optimizing oil and gas companies. His judgement and expertise will be invaluable as we continue improving EP Energy. Bart's impressive career spans accounting, finance, corporate controls, operations and other pertinent areas. His acumen and candor will further strengthen and energize our company. The board is confident that EP Energy will greatly benefit from the knowledge and perspectives of these two exceptional individuals."
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Jan. 22, 2018 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today provided its outlook for 2018 with an increased focus on improving capital efficiency and asset value.
Key Highlights Include:
2017 Achievements
2018 Outlook
1 Percent hedged based on midpoint of 2018 production guidance
"We are excited about our future as we look to build on our recent success and grow cash flows, reduce costs and improve capital efficiency," said Russell Parker, president and chief executive officer of EP Energy Corporation. "In addition to hitting our targets in 2017, we increased our financial flexibility and established a solid path for further improvement to our balance sheet. We have entered into the largest acquisition in our company's history with a bolt on to our high-quality Eagle Ford position in a leverage neutral manner by divesting of a small portion of our Altamont acreage. During the year, we also entered into two drilling joint ventures, which increased capital efficiency. We continue to explore opportunities within each program to further increase asset performance and returns. As we look ahead, 2018 will be a year in which we blend fresh concepts and explore new opportunities across the company to drive higher value for all of our stakeholders."
2017 Preliminary Results
EP Energy expects to achieve its 2017 production target with preliminary equivalent production of 82.3 MBoe/d, including 46.1 MBbls/d of oil production for the year ended December 31, 2017. The company had approximately $700 million of liquidity at December 31, 2017 pro forma for the debt exchange completed in January 2018.
Hedge Program Update
EP Energy has a substantial portion of 2018 oil volumes hedged with a floor of $58.46 per barrel. The company's hedge structures allow for significant upside participation as WTI prices rise. Approximately two-thirds of 2018 oil exposure is open to upward price moves above current strip.
A summary of the company's 2018 and 2019 hedge positions is listed below:
2018 |
2019 |
|||||||
Oil volumes (MMBbls) |
14.94 |
0.73 |
||||||
Average ceiling price ($/Bbl) |
$ |
63.96 |
$ |
55.88 |
||||
Average floor price ($/Bbl) |
$ |
58.46 |
$ |
55.88 |
||||
Natural gas volumes (TBtu) |
25.55 |
7.30 |
||||||
Average ceiling price ($/MMBtu) |
$ |
3.04 |
$ |
2.97 |
||||
Average floor price ($/MMBtu) |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of January 10, 2018 (Contract months: January 1, 2018 - Forward). If market prices settle at or below $50.00 in 2018, EPE will receive a "locked-in" cash settlement of the market price plus $10.00 per Bbl. As of December 31, 2017, the average forward price of oil was $59.31 per Bbl for 2018. |
2018 Outlook
Capital Program
In 2018, EP Energy expects capital spending to range from $600 million to $650 million and meaningfully grow Adjusted EBITDAX1. Included in this range, the company has allocated approximately 10 percent of its spending for new concepts. Approximately 50 percent of the company's capital program is allocated to the Eagle Ford, 30 percent to the Permian and 20 percent to the Altamont.
1 See non-GAAP terms for definition
Production Volumes
Equivalent production in 2018 is expected to range from 81 MBoe/d to 87 MBoe/d with 46 MBbls/d to 50 MBbls/d of oil production.
Operations
During 2018, EP Energy expects to run a five-rig program with one to two rigs in the Eagle Ford, one rig in the Permian and two rigs in the Altamont program.
In the Eagle Ford, the company maintains a highly efficient capital program. In December 2017, the company announced an acquisition that will add current production volumes and expand its acreage position by 26 percent. The transaction, which is expected to close in early February, will increase future drilling inventory across its large contiguous position and allow for operational synergies.
In the Permian, the company will continue to focus on improving well performance across its acreage and reducing operating costs.
In the Altamont, the company expects to continue its drilling joint venture and to expand its capital efficient recompletion program in 2018.
In 2018, EP Energy expects to increase cash flow1 with increased capital efficiencies and reduced operating costs. The table below summarizes the company's operational and financial guidance for the year.
2018 | ||
Oil production (MBbls/d) |
46 – 50 | |
Total production (MBoe/d) |
81 – 87 | |
Oil & Gas Expenditures ($ million)2,3 |
$600 - $650 | |
Eagle Ford |
~50% | |
Permian |
$ |
~30% |
Altamont |
~20% | |
Average gross drilling rigs |
||
Eagle Ford |
1 – 2 | |
Permian |
1 | |
Altamont |
2 | |
Operating Costs |
||
Lease operating expense ($/Boe) |
$5.00 - $5.70 | |
G&A expense ($/Boe) |
$2.90 - $3.25 | |
Adjusted G&A expense ($/Boe)4 |
$2.30 - $2.60 | |
Transportation and commodity purchases ($/Boe) |
$3.15 - $3.45 | |
Taxes, other than income ($/Boe)5 |
$2.50 - $2.60 | |
DD&A ($/Boe) |
$16.50 - $17.50 | |
1 Defined as Adjusted EBITDAX less oil & gas expenditures, excluding acquisition capital. |
2 Includes ~$135 million non-drill capital including; ~$55 million for general equipment, ~$30 million for capitalized G&A and interest, ~$25 million for enhanced facility projects, ~$10 million for EOR projects, and ~$15 million for leasing and seismic, and excludes net acquisition costs and divestiture proceeds of ~$57 million. |
3 Altamont capital includes ~100 recompletions for $50 million. |
4 Adjusted G&A represents G&A expense less approximately $0.60-$0.65 per BOE of non-cash compensation expense. |
5 Severance taxes are based on $55/Bbl WTI. |
Webcast Information
EP Energy has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on January 23, to discuss its 2018 Outlook. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 4247904) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through February 23, 2018 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID #10116378).
About EP Energy
The EP Energy team is driven to deliver superior returns for our investors by developing the oil and natural gas that feeds America's growing energy needs. The company focuses on enhancing the value of its high quality asset portfolio, increasing capital efficiency, maintaining financial flexibility, and pursuing accretive acquisitions and divestitures. EP Energy is working to set the standard for efficient development of hydrocarbons in the U.S. Learn more at epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under these programs adjusted for cash payments made under these plans), transition, restructuring and other costs that affect comparability, gains and losses on extinguishment/modification of debt and impairment charges.
EBITDAX and Adjusted EBITDAX are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
EBITDAX and Adjusted EBITDAX have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. EBITDAX and Adjusted EBITDAX should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Our presentation of EBITDAX and Adjusted EBITDAX may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of EBITDAX and Adjusted EBITDAX should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense under our long-term incentive programs adjusted for cash payments under these plans. This non-GAAP measure is used by management and investors as additional information as noted above and is subject to the same limitations of analytical tools as noted above and should not be considered as a GAAP substitute for general and administrative expense.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas, and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Dec. 29, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced the expiration and final results for the previously announced exchange offers ("Exchange Offers") and consent solicitations ("Consent Solicitations") that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), launched on November 20, 2017 and amended on December 13, 2017 and December 15, 2017, to exchange up to $1.2 billion aggregate principal amount of new 9.375% Senior Secured Notes due 2024 (the "New Notes") and cash for the Issuers' (i) 9.375% Senior Notes due 2020 (the "2020 Notes"), (ii) 7.750% Senior Notes due 2022 (the "2022 Notes") and/or (iii) 6.375% Senior Notes due 2023 (the "2023 Notes" and together with the 2020 Notes and the 2022 Notes, the "Old Notes").
As of 5:00 p.m. New York City time, on December 28, 2017 (the "Expiration Time") according to information provided by D.F. King & Co., Inc., (i) $954,144,000 in aggregate principal amount, or approximately 79.50%, of the 2020 Notes were validly tendered, (ii) $53,641,000 in aggregate principal amount, or approximately 21.45%, of the 2022 Notes were validly tendered and (iii) $139,307,000 in aggregate principal amount, or approximately 26.87%, of the 2023 Notes were validly tendered. All conditions of the Exchange Offers have been satisfied or waived and the Issuers have accepted for purchase all validly tendered Old Notes, and as a result, approximately $1.1 billion in aggregate principal amount of New Notes will be issued and an aggregate $47,707,200 in cash (excluding accrued but unpaid interest) will be paid to participating holders upon settlement of the Exchange Offers, which is expected to occur on January 3, 2018.
General
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. Credit Suisse Securities (USA) LLC acted as dealer manager for the Exchange Offers. D.F. King & Co., Inc. acted as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 22, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that, EP Energy and Everest Acquisition Finance Inc. (together, the "Issuers") entered into a second supplemental indenture (the "Supplemental Indenture") to the indenture (the "Indenture") governing the Issuers' 9.375% Senior Notes due 2020 (the "2020 Notes"). As previously announced, the Issuers received the requisite consents to amend the Indenture on December 19, 2017 at the Early Tender Time of the offers to exchange (the "Exchange Offers") up to $1,200.0 million aggregate principal amount of the Issuers' new 9.375% Senior Secured Notes due 2024 (the "New Notes") and cash for the Issuers' (i) 2020 Notes, (ii) 7.750% Senior Notes due 2022 (the "2022 Notes") and (iii) 6.375% Senior Notes due 2023 (the "2023 Notes" and together with the 2020 Notes and the 2022 Notes, the "Old Notes") and the related consent solicitations (the "Consent Solicitations").
The Supplemental Indenture, among other things, eliminates substantially all of the restrictive covenants and certain events of default from the Indenture. The Supplemental Indenture became effective immediately upon execution but will not become operative until the Exchange Offer with respect to the 2020 Notes is consummated. Upon becoming operative, the amendments to the Indenture will apply to all holders of the 2020 Notes.
General
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 20, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced the early tender results as of 5:00 p.m. New York City time on December 19, 2017 (the "Early Tender Time") of the previously-announced exchange offers ("Exchange Offers") and consent solicitations ("Consent Solicitations") that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), launched on November 20, 2017 and amended on December 13, 2017 and December 15, 2017 to exchange up to $1.2 billion aggregate principal amount of new 9.375% Senior Secured Notes due 2024 (the "New Notes") and cash for the Issuers' (i) 9.375% senior notes due 2020 (the "2020 Notes"), (ii) 7.75% senior notes due 2022 (the "2022 Notes") and/or (iii) 6.375% senior notes due 2023 (the "2023 Notes" and together with the 2020 Notes and the 2022 Notes, the "Old Notes").
According to information provided by D.F. King & Co., Inc., as of the Early Tender Time (i) $891,608,000 in aggregate principal amount, or approximately 74.29%, of the 2020 Notes have been validly tendered and not validly withdrawn, (ii) $44,872,000 in aggregate principal amount, or approximately 17.94%, of the 2022 Notes and $103,686,000 in aggregate principal amount, or approximately 20.00% of the 2023 Notes with Priority 2 Acceptance Level have been validly tendered and not validly withdrawn and (iii) $8,533,000 in aggregate principal amount, or approximately 3.41%, of the 2022 Notes and $35,346,000 in aggregate principal amount, or approximately 6.82%, of the 2023 Notes with Priority 3 Acceptance Level have been validly tendered and not validly withdrawn.
The Issuers have amended the terms of the Exchange Offers to provide that all holders that tender Old Notes prior to the 5:00 p.m. New York City time on December 28, 2017 (the "Expiration Time") will receive the Total Consideration for such Old Notes set forth in the Confidential Offering Memorandum and Consent Solicitation, dated November 20, 2017 (as supplemented on December 13, 2017 and December 15, 2017, the "Offering Memorandum"). Holders of Old Notes who have not already tendered their Old Notes and delivered their consents may continue to do so at any time prior to the Expiration Time pursuant to the terms set forth in the Offering Memorandum. Because the Withdrawal Date has passed, holders who validly tender their notes or have already tendered their notes may no longer withdraw such notes.
General
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 15, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), announced that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), have amended certain terms of the previously-announced exchange offers (the "Exchange Offers") and consent solicitations (the "Consent Solicitations") that they launched on November 20, 2017 and amended on December 13, 2017 to exchange up to $1.2 billion aggregate principal amount (subject to change, the "Maximum Exchange Amount") of new 9.375% Senior Secured Notes due 2024 (the "New Notes") and cash for the Issuers' outstanding 9.375% senior note due 2020, 7.750% senior notes due 2022 and 6.375% senior notes due 2023 (collectively, the "Old Notes").
The early tender time for the Exchange Offers and Consent Solicitations remains 5:00 p.m., New York City time, on December 19, 2017 (the "Early Tender Time") and the expiration time for the Exchange Offers and Consent Solicitations remains 5:00 p.m., New York City time, on December 28, 2017. Holders of the Old Notes that validly tender their Old Notes prior to the Early Tender Time will be entitled to the previously-announced terms and conditions of the Exchange Offers and Consent Solicitations as set forth in the Confidential Offering Memorandum and Consent Solicitation Statement, dated November 20, 2017 (as supplemented on December 13, 2017, the "Offering Memorandum"), except as set forth herein.
The Issuers have amended the terms of the New Notes being offered in the Exchange Offers by (i) inserting in clause (7) of the definition of "Permitted Liens" in the section of the Offering Memorandum entitled "Description of New Notes—Certain Definitions" immediately after the text "the holders of the 2024 Priority Senior Secured Notes" the following: ", the holders of the 2025 Senior Secured Notes (and any additional Indebtedness issued under the 2025 Senior Secured Notes Indenture)"; and (ii) deleting "of any amendment thereto or pursuant to a new loan agreement" immediately after the text "in each case" in the definition of "RBL Facility" in the section of the Offering Memorandum entitled "Description of New Notes—Certain Definitions." Except as set forth herein, the complete terms and conditions of the Exchange Offers and Consent Solicitations remain the same as set forth and detailed in the Offering Memorandum, copies of which were previously distributed to eligible holders of the Old Notes.
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. The offering documents will be distributed only to holders of the Old Notes that complete and return a letter of eligibility confirming that they are "Eligible Holders" for the purposes of the Exchange Offers. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 14, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today announced that it has entered a definitive agreement with Carrizo Oil & Gas, Inc. to acquire certain producing properties and undeveloped acreage from existing Eagle Ford operating areas primarily in LaSalle County in South Texas. The company also announced it has entered into a definitive agreement with an undisclosed party to divest certain assets in the Altamont area of the Uinta Basin. The aggregate cash purchase price for the acquired properties is approximately $245 million, while the divested properties will generate estimated proceeds of $180 million. The company expects to close both transactions in Q1 2018, and both are subject to customary closing adjustments.
"These transactions are consistent with our strategy of focusing on adding high-quality assets in areas where we have a competitive advantage," said Russell Parker, president and chief executive officer of EP Energy Corporation. "Our new team has a strong record of enhancing asset performance, and we are excited about the opportunities we see at EP Energy. Generating improved returns is a key driver as we look across the company to optimize our capital program. We are pleased to enhance our portfolio, while divesting assets at a high value, and we are doing so in a cash flow and balance sheet friendly manner."
Summary:
Acquisition
Divestiture
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward‐looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; changes in commodity prices and basis differentials for oil and natural gas; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; political and currency risks associated with international operations of the company; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward‐looking statements made herein or any other forward‐looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Dec. 13, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), announced that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), have amended certain terms of the previously-announced exchange offers (the "Exchange Offers") and consent solicitations (the "Consent Solicitations") that they launched on November 20, 2017 to exchange up to $1.2 billion aggregate principal amount (subject to change, the "Maximum Exchange Amount") of new 9.375% Senior Secured Notes due 2024 (the "New Notes") for the Issuers' outstanding Senior Notes listed in the table below (collectively, the "Old Notes"). The Issuers have negotiated these terms with a steering committee of holders of the 2020 Notes represented by Akin Gump Strauss Hauer & Feld LLP. Members of the steering committee have indicated that such terms are acceptable to them.
The Issuers also announced that they have extended the early tender time for the Exchange Offers and Consent Solicitations to 5:00 p.m., New York City time, on December 19, 2017 (the "Early Tender Time") and the expiration time for the Exchange Offers and Consent Solicitations to 5:00 p.m., New York City time, on December 28, 2017. Holders of the Old Notes that validly tender their Old Notes prior to the Early Tender Time will be entitled to the previously-announced terms and conditions of the Exchange Offers and Consent Solicitations, except as set forth herein and in the Supplement No. 1, dated December 13, 2017 (the "Offering Memorandum Supplement"), to the Confidential Offering Memorandum and Consent Solicitation Statement, dated November 20, 2017 (the "Offering Memorandum").
As part of the amendments, the Issuers increased the total consideration payable to holders of 9.375% Senior Notes due 2020 ("2020 Notes") to (i) $50.00 in cash and (ii) $1,000 of New Notes, per $1,000 principal amount of 2020 Notes validly tendered and not withdrawn prior to the Early Tender Time. In addition, the Issuers agreed to significant improvements to the terms of the New Notes as described further below.
The Old Notes and other information relating to the Exchange Offers are set forth below. As of 5:00 p.m., New York City time, on December 13, 2017, the principal amount of Old Notes validly tendered and not validly withdrawn was $44,482,000 with respect to the 2020 Notes, $9,864,000 with respect to the 7.750% Senior Notes due 2022 ("2022 Notes") and $76,721,000 with respect to the 6.375% Senior Notes due 2023 ("2023 Notes").
Consideration per $1,000 Principal Amount of Old | |||||
Title of Old |
CUSIP/ISIN |
Outstanding |
Acceptance |
Total |
Exchange |
9.375% Senior Notes due 2020(1) |
29977HAB6 / US29977HAB69 |
$1,200,204,000 |
1 |
$1,000 aggregate principal amount of New Notes and $50.00 in cash |
$950 aggregate principal amount of New Notes |
7.750% Senior Notes due 2022, subject to the Priority Level 2 Condition(2) |
268787AB4 / US268787AB41 |
$250,060,000 |
2 |
$725 aggregate principal amount of New Notes
|
$675 aggregate principal amount of New Notes
|
6.375% Senior Notes due 2023, subject to the Priority Level 2 Condition(2) |
268787AD0 / US268787AD07 |
$518,518,000 |
2 |
$725 aggregate principal amount of New Notes
|
$675 aggregate principal amount of New Notes
|
7.750% Senior Notes due 2022 |
268787AB4 / US268787AB41 |
$250,060,000 |
3 |
$700 aggregate principal amount of New Notes
|
$650 aggregate principal amount of New Notes
|
6.375% Senior Notes due 2023 |
268787AD0 / US268787AD07 |
$518,518,000 |
3 |
$700 aggregate principal amount of New Notes
|
$650 aggregate principal amount of New Notes
|
___________________
(1) |
All 2020 Notes are Acceptance Priority Level 1 notes ("Priority 1 Notes"). In the event that an aggregate principal amount of 2020 Notes tendered exceeds the Maximum Exchange Amount, the Issuers intend to increase the Maximum Exchange Amount in order to accept all 2020 Notes tendered. In addition, under certain circumstances, the Issuers may increase the Maximum Exchange Amount to up to $1,400.0 million based on demand in the Exchange Offers. |
(2) |
Any Eligible Holder who tenders 2020 Notes is also eligible to exchange 2022 Notes or 2023 Notes (or a combination thereof), up to the amount of 2020 Notes tendered by such Eligible Holder (with such 2022 Notes and 2023 Notes to be accepted on a pro rata basis), as Acceptance Priority Level 2 notes ("Priority 2 Notes"); provided that if an Eligible Holder tenders both 2022 Notes and 2023 Notes, only pro rata amounts of the 2022 Notes and 2023 Notes, the sum of which equals the total amount of 2020 Notes tendered by such holder, will be eligible for Acceptance Priority Level 2 (the "Priority Level 2 Condition"). Any 2022 Notes and 2023 Notes tendered in excess of the amount of 2020 Notes tendered by an Eligible Holder will be eligible for acceptance on a pro rata basis under Acceptance Priority Level 3 ("Priority 3 Notes"). |
The Issuers have also amended the terms of the New Notes being offered in the Exchange Offers to: (i) provide for optional redemptions prior to May 1, 2020 at a redemption price equal to 100% of principal amount plus the applicable "make-whole" premium (calculated based on present value of the redemption price at May 1, 2020 using a discount rate equal to the treasury rate plus 50 basis points), (ii) provide for optional redemptions at redemption prices of 107.031%, 104.688%, 102.344% and 100.000% for redemptions during the 12-month periods commencing May 1, 2020, 2021, 2022 and 2023 and thereafter, respectively, (iii) reduce the amount of New Notes that can be redeemed with net cash proceeds from equity offerings from 50% to 35%, (iv) prohibit subsidiary guarantees and collateral from being released or terminated automatically solely due to a release or termination under other indebtedness, (v) set an aggregate incurrence cap of $2,400 million for indebtedness that is secured by liens on collateral that are pari passu with liens on collateral securing the New Notes, (vi) revise the definition of "RBL Facility" to refer to a facility with commercial bank lenders and a borrowing base determined in accordance with customary oil and gas lending criteria, (vii) make the prepayment of any outstanding Old Notes more than one year prior to maturity a restricted payment, with exceptions permitting the refinancing of such Old Notes with unsecured indebtedness or secured indebtedness that is secured by liens on collateral that are junior to or pari passu with liens on collateral securing the New Notes, (viii) calculate "Cumulative Credit" from October 1, 2017 rather than July 1, 2012 and "Excluded Contributions" from the issue date of the New Notes rather than the issue date of the 2020 Notes and (ix) place a $500 million sublimit on aggregate amounts outstanding after the issue date under the following Investment and Restricted Payment baskets and carve-outs: investments in unrestricted subsidiaries, general investments, investments in similar businesses, general restricted payments, distribution of stock of unrestricted subsidiaries and annual dividend basket up to 6% of market capitalization. The amended terms of the New Notes are described in more detail in the Offering Memorandum Supplement.
Except as set forth herein and in the Offering Memorandum Supplement, the complete terms and conditions of the Exchange Offers and Consent Solicitations remain the same as set forth and detailed in the Offering Memorandum, copies of which were previously distributed to eligible holders of the Old Notes.
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. The offering documents will be distributed only to holders of the Old Notes that complete and return a letter of eligibility confirming that they are "Eligible Holders" for the purposes of the Exchange Offers. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 11, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that it has further extended the early tender time until 5:00 p.m., New York City time, on December 13, 2017 (the "Extended Early Tender Time"), with respect to its previously-announced exchange offers (the "Exchange Offers") and consent solicitations (the "Consent Solicitations") that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), launched on November 20, 2017 to exchange up to $1.2 billion aggregate principal amount (subject to change, the "Maximum Exchange Amount") of new 9.375% Senior Secured Notes due 2024 (the "New Notes") for the Issuers' outstanding Senior Notes (collectively, the "Old Notes") as described in the confidential offering memorandum and consent solicitation statement, dated November 20, 2017 (the "Offering Memorandum"). The deadline to validly withdraw tenders of Old Notes expired at 5:00 p.m., New York City time, on December 4, 2017 (the "Withdrawal Deadline").
Holders of the Old Notes that validly tender their Old Notes prior to the Extended Early Tender Time will still be entitled to the Total Consideration (as defined in the Offering Memorandum) on the previously-announced terms and conditions of the Exchange Offers and Consent Solicitations. Except as set forth herein, the complete terms and conditions of the Exchange Offers and Consent Solicitations remain the same as set forth and detailed in the Offering Memorandum, copies of which were previously distributed to eligible holders of the Old Notes.
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. The offering documents will be distributed only to holders of the Old Notes that complete and return a letter of eligibility confirming that they are "Eligible Holders" for the purposes of the Exchange Offers. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Dec. 5, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that it has extended the early tender time until 5:00 p.m., New York City time, on December 8, 2017 (the "Extended Early Tender Time"), with respect to its previously-announced exchange offers (the "Exchange Offers") and consent solicitations (the "Consent Solicitations") that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), launched on November 20, 2017 to exchange up to $1.2 billion aggregate principal amount (subject to change, the "Maximum Exchange Amount") of new 9.375% Senior Secured Notes due 2024 (the "New Notes") for the Issuers' outstanding Senior Notes (collectively, the "Old Notes") as described in the confidential offering memorandum and consent solicitation statement, dated November 20, 2017 (the "Offering Memorandum"). The deadline to validly withdraw tenders of Old Notes was not extended by the Issuers, and expired at 5:00 p.m., New York City time, on December 4, 2017 (the "Withdrawal Deadline").
Holders of the Old Notes that validly tender their Old Notes prior to the Extended Early Tender Time will still be entitled to the Total Consideration (as defined in the Offering Memorandum) on the previously-announced terms and conditions of the Exchange Offers and Consent Solicitations. Except as set forth herein, the complete terms and conditions of the Exchange Offers and Consent Solicitations remain the same as set forth and detailed in the Offering Memorandum, copies of which were previously distributed to eligible holders of the Old Notes.
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. The offering documents will be distributed only to holders of the Old Notes that complete and return a letter of eligibility confirming that they are "Eligible Holders" for the purposes of the Exchange Offers. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy Corporation
HOUSTON, Nov. 20, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), have launched exchange offers (the "Exchange Offers") to exchange up to $1.2 billion aggregate principal amount (subject to change, the "Maximum Exchange Amount") of new 9.375% Senior Secured Notes due 2024 (the "New Notes") for the Issuers' outstanding Senior Notes listed in the table below (collectively, the "Old Notes").
Exchange Offers
The Old Notes and other information relating to the Exchange Offers are set forth below.
Consideration per $1,000 Principal Amount of Old Notes Tendered | ||||||||||
Title of Old |
CUSIP/ISIN Number(s) |
Outstanding |
Acceptance Priority Level |
Total |
Exchange | |||||
9.375% Senior Notes due 2020(1) |
29977HAB6 / US29977HAB69 |
$1,200,204,000 |
1 |
$1,000 aggregate principal amount of New Notes |
$950 aggregate principal amount of New Notes | |||||
7.750% senior notes due 2022, subject to the Priority Level 2 Condition(2) |
268787AB4 / US268787AB41 |
$250,060,000 |
2 |
$725 aggregate principal amount of New Notes
|
$675 aggregate principal amount of New Notes
| |||||
6.375% senior notes due 2023 subject to the Priority Level 2 Condition(2) |
268787AD0 / US268787AD07 |
$518,518,000 |
2 |
$725 aggregate principal amount of New Notes
|
$675 aggregate principal amount of New Notes
| |||||
7.750% senior notes due 2022 |
268787AB4 / US268787AB41 |
$250,060,000 |
3 |
$700 aggregate principal amount of New Notes
|
$650 aggregate principal amount of New Notes
| |||||
6.375% senior notes due 2023 |
268787AD0 / US268787AD07 |
$518,518,000 |
3 |
$700 aggregate principal amount of New Notes
|
$650 aggregate principal amount of New Notes
|
(1) |
All 2020 Notes are Acceptance Priority Level 1 notes ("Priority 1 Notes"). In the event that an aggregate principal amount of 2020 Notes tendered exceeds the Maximum Exchange Amount, the Issuers intend to increase the Maximum Exchange Amount in order to accept all 2020 Notes tendered. In addition, under certain circumstances, the Issuers may increase the Maximum Exchange Amount to up to $1,400 million based on demand in the Exchange Offers. | ||||||
(2) |
Any Eligible Holder who tenders 2020 Notes is also eligible to exchange 2022 Notes or 2023 Notes (or a combination thereof), up to the amount of 2020 Notes tendered by such Eligible Holder (with such 2022 Notes and 2023 Notes to be accepted on a pro rata basis), as Acceptance Priority Level 2 notes ("Priority 2 Notes"); provided that if an Eligible Holder tenders both 2022 Notes and 2023 Notes, only pro rata amounts of the 2022 Notes and 2023 Notes, the sum of which equals the total amount of 2020 Notes tendered by such holder, will be eligible for Acceptance Priority Level 2 (the "Priority Level 2 Condition"). Any 2022 Notes and 2023 Notes tendered in excess of the amount of 2020 Notes tendered by an Eligible Holder will be eligible for acceptance on a pro rata basis under Acceptance Priority Level 3 ("Priority 3 Notes"). |
Additional Information
Subject to the limitations described in the confidential offering memorandum and consent solicitation statement (the "Offering Memorandum") and to proration (if necessary), Old Notes properly tendered (and not withdrawn) will be accepted in order of the Acceptance Priority Levels indicated in the table above, with Level 1 being the highest priority level and 3 being the lowest priority level. In determining whether the Maximum Exchange Amount is exceeded at a particular Acceptance Priority Level, all New Notes required to be issued and all Old Notes required to be accepted in higher priority levels will be included. Old Notes properly tendered (and not withdrawn) will be accepted by the Issuers in the Exchange Offers in the following order and the following amounts:
The Issuers will pay accrued and unpaid interest on the Old Notes exchanged for New Notes on the settlement date for the Exchange Offer.
The Exchange Offers are not conditioned on a minimum principal amount of outstanding Old Notes being tendered or the issuance of a minimum principal amount of New Notes. However, the Exchange Offer is subject to certain other conditions, as more fully described in the Offering Memorandum.
In connection with the Exchange Offers, the Issuers will solicit consents to amend the Old Notes and the indentures governing the Old Notes (the "Old Notes Indentures"). The proposed amendments, which require the consent of a majority in aggregate principal amount of the outstanding Old Notes with respect to each series of Old Notes, will eliminate or waive substantially all of the restrictive covenants, eliminate certain events of default, modify covenants regarding mergers and transfers of assets, and modify or eliminate certain other provisions in the Old Notes Indentures. The Issuers will not accept consents for the 2022 Notes or the 2023 Notes if less than the full amount of tendered 2022 Notes and 2023 Notes are accepted pursuant to the Exchange Offers.
The New Notes will be issued pursuant to an indenture by and among the Issuers, the guarantors and Wilmington Trust, National Association, as trustee and collateral agent. The New Notes will bear interest at a rate of 9.375% per annum, will mature on May 1, 2024 and will be governed by covenants that are substantially the same as the covenants currently governing the Issuers' 8.00% Senior Secured Notes due 2025. The New Notes will be fully and unconditionally guaranteed, jointly and severally, by each of the Issuers' restricted subsidiary guarantors (including those obligated with respect to certain indebtedness, including the Issuers' senior reserve-based revolving credit facility), and such guarantees and the New Notes will be secured by junior priority security interests in the collateral that secures the Issuers' obligations under the RBL Facility. On the issue date of the New Notes, the collateral for the New Notes will include substantially all of the acreage in the Issuer's core areas that it currently holds. The New Notes will rank in seniority equal with any existing and future senior indebtedness, as further described in the Offering Memorandum. The liens securing the New Notes will rank pari passu in priority with the Issuers' 8.00% senior secured notes due 2025. The terms of the New Notes will not permit incurrence of additional secured debt that ranks pari passu in lien priority in excess of $1,200 million, except to the extent the amount of New Notes issued in the Exchange Offers is increased.
General
The Issuers may terminate, withdraw or amend the Exchange Offers and Consent Solicitations, either as a whole, or with respect to one or more series of Old Notes, at any time and for any reason, including based on the acceptance rate and outcome of the Exchange Offers or if any of the conditions described in the Offering Memorandum are not satisfied, subject to applicable law.
The issuance of the New Notes will not be registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws. The New Notes are being offered and issued only (1) in the United States to holders of the Old Notes that are "qualified institutional buyers" as defined in Rule 144A under the Securities Act, and (2) outside the United States to holders of the Old Notes that are not U.S. persons in reliance upon Regulation S under the Securities Act. Accordingly, the New Notes will be subject to restrictions on transferability and resale and may not be transferred or resold except as permitted under the Securities Act and other applicable securities laws, pursuant to registration or exemption therefrom.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful. The offering documents will be distributed only to holders of the Old Notes that complete and return a letter of eligibility confirming that they are "Eligible Holders" for the purposes of the Exchange Offers. D.F. King & Co., Inc. is acting as the Information Agent for the Exchange Offers. Requests for the offering documents from "Eligible Holders" may be directed to D.F. King & Co., Inc. at (212) 269-5550 (for brokers and banks) or (800) 207-3158 (for all others).
Neither the Issuers, their respective boards nor any other person makes any recommendation as to whether the holders of the Old Notes should exchange their notes, and no one has been authorized to make such a recommendation. Holders of the Old Notes must make their own decisions as to whether to exchange their notes, and if they decide to do so, the principal amount of the notes to exchange.
About EP Energy LLC
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy LLC
HOUSTON, Nov. 6, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) announced today that its Third Quarter Report on Form 10-Q has been filed and Russell Parker has assumed the role of President and Chief Executive Officer of EP Energy Corporation.
As previously announced, Brent Smolik continues to work closely with the company to ensure a smooth transition to Mr. Parker.
Along with Mr. Parker the new leadership team includes: Ray Ambrose – Senior Vice President of Engineering and Subsurface, Chad England – Senior Vice President of Operations, Mark Hargis – Vice President of Geoscience, and Peter Addison – Vice President of Land and Land Administration.
As previously filed in the company's Form 8-K on November 2, 2017 and include here pursuant to New York Stock Exchange Listing Rule 303A.08, EP Energy granted employment inducement awards to Russell Parker, Ray Ambrose, Chad England, Peter Addison and Mark Hargis consisting of (i) 188,679, 150,943, 150,943, 113,207 and 113,207, respectively, shares of restricted Class A common stock of the company, which vest ratably over four years and (ii) 240,000, 168,000, 168,000, 168,000 and 168,000, respectively, performance share units, which represent a right to receive Class A common stock of the company based on the achievement of specified stock price goals over a four-year performance period.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Note to Editor:
Information on new management members:
Russell Parker
Russell Parker is the President and Chief Executive Officer of EP Energy Corporation and serves as a member of its Board of Directors. He previously served as Chief Executive Officer for Phoenix Natural Resources. Mr. Parker began his career at Platt, Sparks & Associates, a petroleum engineering consulting firm. In 2001, he joined Hilcorp Energy Company as a Reservoir Engineer. During 12 years with the company, he held a variety of roles working assets, corporate reserves and A&D as Reservoir Engineer. In 2007, he became the Asset Team Leader for Tom O'Connor which later became the South Texas Region. In 2009, when Hilcorp began its first unconventional project, Mr. Parker served as the Asset Team Leader executing development of the Eagle Ford program from inception to the ultimate sale to Marathon in late 2011. After the sale, he led the first Asset Team to work the Appalachian basin for Hilcorp. In 2012, Mr. Parker joined Chief Oil & Gas based in Dallas and focused on the Marcellus. After serving as VP of engineering and acquisitions and SVP of engineering and operations, Mr. Parker was later promoted to President. He has been recognized as an Outstanding Young Graduate of the Cockrell School of Engineering as well as a Distinguished Alumnus of the Petroleum Engineering Department at the University of Texas at Austin.
Ray Ambrose
Ray Ambrose is the Senior Vice President of Engineering and Subsurface for EP Energy Corporation. He previously served as Senior Vice President Engineering and Business Development for Phoenix Natural Resources. Mr. Ambrose has vast experience in North American unconventional reservoirs and secondary/tertiary recovery techniques, including water and CO2 flooding. He has held positions of increasing responsibility including Director of Petroleum Engineering & Subsurface at NRG, Chief Reservoir Engineer at Hilcorp Energy Company and Director of Reservoir Engineering for Reliance USA. Mr. Ambrose earned his BS in chemical engineering with petroleum minor in 1996 and MS in petroleum engineering in 2006 from the University of Southern California. While working for Devon and Reliance, he completed his PhD in petroleum engineering from the University of Oklahoma in 2011 where his dissertation focused on unconventional gas storage phenomena and rate transient analysis of unconventional reservoirs.
Chad England
Chad England is the Senior Vice President of Operations for EP Energy Corporation. He previously served as Senior Vice President of Operations for Phoenix Natural Resources. Previously, he worked for Hilcorp Energy as an Operations Manager and Engineer for the Eagle Ford, Utica, and South Texas asset teams. During his tenure with the company, he was responsible for completions, production and facilities along with managing teams of employees and contractors. He also managed all aspects of operational integration associated with acquisitions including all hiring. Prior to Hilcorp, Mr. England served in various engineering roles at ConocoPhillips for the Eagle Ford, South Louisiana, and Gulf of Mexico. He earned a BS in Mechanical Engineering from Texas A&M University.
Mark Hargis
Mark Hargis is the Vice President of Geoscience for EP Energy. He previously served as Senior Vice President of Geoscience for Phoenix Natural Resources. Mr. Hargis brings over 30 years of both technical and management experience covering multiple North American basins throughout the United States. He most recently held a senior technical position at Hilcorp Energy evaluating and developing portfolio fields in the heavily salt influenced trend of South Louisiana. Prior to Hilcorp, he served as the Vice President of Geoscience at Legend Natural Gas, a private equity backed company, which was active in the Texas Gulf Coast, the Delaware Basin and the Fort Worth Basin. During that time, Mr. Hargis provided technical oversight and led teams of geoscientists and engineers in the development and exploration of both conventional and unconventional reservoirs. Before Legend, he worked in various geological technical assignments with privately owned North Central Oil Corporation and Shell Oil Company where he began his career. Mr. Hargis earned his BS in Geological Engineering from the University of Missouri – School of Mines. Additionally, he is an active member of the American Association of Petroleum Geologists.
Peter Addison
Peter Addison is the Vice President of Land and Land Administration for EP Energy. He previously served as Senior Vice President of Land for Phoenix Natural Resources. Mr. Addison brings over 30 years of land experience, including E&P and A&D, covering multiple basins throughout the United States. He most recently held a senior officer position at Castex Energy, managing all land activities for fields in South Louisiana and the OCS. During that time, he led all aspects of the land function, also serving as project manager for a large, multi-participant 3-D seismic project in SOLA. Prior to Castex, he served as the Chief Land Officer at Reliance USA, a U.S. subsidiary of Reliance Holdings, Ltd., which is active in the unconventional Marcellus Shale in Pennsylvania and the Eagle Ford Shale in Texas. Before Reliance, he worked in various staff and management assignments with Swift Energy, Texas Meridian, Pioneer Natural Resources and Shell Western E&P, where he began his career. Mr. Addison earned his BS in Petroleum Land Management from Louisiana State University. Additionally, he is an active member of the American Association of Professional Landmen and maintains professional certification.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, Nov. 1, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported third quarter 2017 financial and operational results and changes in the company's senior leadership.
Third Quarter 2017
"In the third quarter, we continued to execute in each capital program and are on track to achieve our 2017 goals," said Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation. "The company is well positioned in three core areas with a demonstrated track record of execution. Looking forward, we are also announcing several leadership changes. I thank all of the leaders and team members that helped us to reach this juncture and welcome the new leadership team to the company."
Senior Leadership Changes
EP Energy is announcing a change in senior leadership. Effective today, Brent Smolik and several other officers including Clay Carrell – EVP and COO, Joan Gallagher – SVP, HR & Administrative Services, and Marguerite Woung-Chapman – SVP and General Counsel will begin transitioning their respective responsibilities to new management team members and then depart the organization.
Russell Parker will become President and CEO of EP Energy once the company files its Form 10-Q for the third quarter. He will be leading a new streamlined management structure with new team leaders –Chad England (Operations), Ray Ambrose (Engineering & Subsurface), Mark Hargis (G&G) and Pete Addison (Land and Admin). The new team will also include current leaders – Kyle McCuen (Interim CFO), Frank Olmsted (CAO) and Dennis Price (Marketing). These key changes are an initial step in moving from an asset-based to a function-based organization. This new structure will enable greater flexibility in allocating capital and resources to specific assets, while continuing the company's focus on cost reduction. During the transition, the team will finalize comprehensive plans for moving to a function-based organizational structure, while reviewing 2018 capital allocation options and refining the overall long-term strategy.
Effective November 2, 2017, the Board of Directors has appointed Mr. Alan Crain as Chairman of the Board of EP Energy.
"The board is pleased that Russell and other new members are joining the EP Energy team," said Mr. Crain. "The new team has a record of success in energetically implementing creative solutions to address challenges facing oil and gas operators. With the 2018 planning process about to occur, now is the optimal time for this transition."
"I'm very excited to be joining EP Energy, with its excellent asset base, and to be entrusted with the opportunity to team with the company's outstanding people to take on the challenges that face us," said Mr. Russell Parker.
EP Energy, will continue to operate safely and efficiently while moving expeditiously through the transition. The company thanks the departing management team members for their dedication to building a foundation of quality execution, capital program performance and a high-graded portfolio. With all employees continuing to embrace the core values of EP Energy, the company will build on this foundation and thrive.
Third Quarter Results
EP Energy reported a $(0.29) diluted net loss per share and a $(0.12) adjusted loss per share for the third quarter of 2017. Reported net loss was $72 million for the third quarter of 2017, down from $43 million net loss in the third quarter of 2016. Adjusted EBITDAX for the third quarter of 2017 was $159 million, down from $250 million in the third quarter of 2016 due primarily to $118 million less of hedge settlements in 2017 versus 2016, partially offset by higher production volumes and higher realized pricing on physical sales.
Operating expenses for the third quarter of 2017 were $237 million, down from $249 million in the third quarter of 2016, or $31.79 per Boe for the third quarter of 2017 versus $33.95 per Boe in the third quarter of 2016. Adjusted cash operating costs were $110 million for the third quarter of 2017, up from $107 million in the third quarter of 2016. For the third quarter of 2017, adjusted cash operating costs per unit were $14.73 per Boe, up from $14.50 per Boe for the third quarter of 2016 due primarily to higher lease operating expenses, partially offset by lower general and administrative costs and lower third party commodity purchases. Adjusted cash operating costs in the third quarter 2017 included an accrual relating to a contractual commitment and termination charge of approximately $0.43 per Boe in the quarter.
Total capital expenditures in the third quarter of 2017 were $162 million, including $27 million of acquisition capital. In the third quarter of 2017, the company completed 40 gross wells compared to 30 gross wells in the third quarter of 2016. Average daily oil production was 45.1 MBbls/d in the third quarter of 2017, up slightly from 45.0 MBbls/d in the third quarter of 2016. Total equivalent production was 81.0 thousand barrels of oil equivalent per day (MBoe/d) in the third quarter, up from 79.6 MBoe/d in the same period last year.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
As previously announced, the company executed open-market repurchases of $101 million in July at a discount to face value. The company expects to reduce annualized interest expense as a result of these debt repurchases.
In October, EP Energy successfully completed its semi-annual borrowing base redetermination for its RBL Facility. The value of the facility was renewed at $1.4 billion, essentially in-line with the previous value.
EP Energy continues to prioritize balance sheet improvements and maintaining a strong liquidity position, which was $934 million as of September 30, 2017. The company ended the quarter with approximately $4.0 billion of debt.
Eagle Ford Program
In the third quarter of 2017, EP Energy did not complete any wells in its Eagle Ford program and produced 20.0 MBbls/d of oil, a 17 percent decrease compared with the third quarter of 2016. Total equivalent production for the third quarter of 2017 was 32.9 MBoe/d. The lower production was driven by fewer well completions and the impact from Hurricane Harvey. As previously announced, third quarter production was reduced by approximately 0.9 MBoe/d, including 0.3 MBbls/d of oil, as a result of Hurricane Harvey.
In the third quarter, the company continued to reduce base production decline rates. The company's realized pricing also improved in the third quarter of 2017 as compared with the third quarter of 2016, driven by higher LLS-based pricing.
During the third quarter, EP Energy had one drilling rig active in the Eagle Ford. The company continues to improve returns and operational efficiencies in the program.
Wolfcamp Program
In the third quarter of 2017, EP Energy significantly increased activity in its Wolfcamp program and produced record quarterly oil and total equivalent volumes. In the third quarter of 2017, the company completed 32 gross wells (19.5 net wells) and produced 12.6 MBbls/d of oil, a 35 percent increase compared with the third quarter of 2016. Total equivalent production for the third quarter of 2017 was 29.9 MBoe/d. Production volumes were up compared to previous periods due to higher activity levels.
Also, the company completed several bolt-on acquisitions in Upton County which added current production and future drilling locations. These acquisitions totaled approximately $29 million ($27 million in the third quarter and $2 million in the second quarter) and included approximately 3,600 net acres in Upton County with gross oil production of 300 Bbls/d. The transactions added approximately 60 future drilling locations and enabled the company to extend approximately 20 short lateral locations to long lateral locations.
EP Energy expects continued production increases in the fourth quarter of 2017 and will reduce the number of expected completions as a result of substituting development capital for acquisition capital, higher cost inflation and a slightly higher mix of non-joint venture wells.
Altamont Program
In the third quarter of 2017, EP Energy completed 8 gross wells (3 net wells) in its Altamont program and produced 12.5 MBbls/d of oil, a 7 percent increase compared with third quarter of 2016. Total equivalent production for the third quarter of 2017 was 18.2 MBoe/d, up 8 percent from the third quarter of 2016.
In the third quarter of 2017, realized pricing for Altamont production volumes was 94 percent of WTI as a result of improved contract terms and local market conditions as compared to 92 percent of WTI in the same 2016 period.
EP Energy had two joint venture drilling rigs active in the Altamont during the third quarter and continued to benefit from its successful recompletion program. For the remainder of 2017, the company expects to run two joint venture drilling rigs and continue its recompletion program.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program which provides continued commodity price protection. In the third quarter of 2017, the company realized $27 million of cash settlements on its financial derivatives.
A summary of the company's current open hedge positions including its most recent transactions is listed below:
2017 |
2018 |
2019 |
|||||||||||
Total Fixed Price Hedges |
|||||||||||||
Oil volumes (MMBbls)(1) |
2.5 |
8.9 |
— |
||||||||||
Average floor price ($/Bbl) |
$ |
60.34 |
$ |
60.00 |
$ |
— |
|||||||
Natural Gas volumes (TBtu) |
8.7 |
25.6 |
7.3 |
||||||||||
Average floor price ($/MMBtu) |
$ |
3.28 |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of October 1, 2017 (Contract months: October 2017 - Forward). |
(1) 2017 positions include WTI three way collars of 2.2 MMBbls and 2018 positions include WTI three way collars of 8.9 MMBbls. |
At September 30, 2017, the mark-to-market value of the company's hedge contracts was approximately $64 million.
2017 Outlook
EP Energy expects to maintain its previous full year oil production, capital expenditures, cash operating costs guidance ranges and reduce the number of expected well completions in its Wolfcamp program. The table below summarizes the company's current operational and financial guidance for 2017.
Current Guidance |
|||
Oil production (MBbls/d) |
46 – 48 |
||
Total production (MBoe/d) |
80 – 85 |
||
Oil & Gas capital ($ million)1 |
|||
Wolfcamp |
$250 – $300 |
||
Eagle Ford |
~$200 |
||
Altamont |
~$100 |
||
Total capital program ($ million) |
$550 – $600 |
||
Gross well completions |
|||
Wolfcamp2 |
60 – 80 |
||
Eagle Ford |
~50 |
||
Altamont3 |
~30 |
||
Total |
140 – 160 |
||
GAAP general and administration expense ($/Boe) |
$3.35 – $3.50 |
||
Lease operating expense ($/Boe) |
$5.50 – $5.85 |
||
Adjusted general and administration expense ($/Boe) |
$2.90 – $3.00 |
||
Transportation and commodity purchases ($/Boe) |
$3.85 – $4.25 |
||
Taxes, other than income ($/Boe)4 |
$2.10 – $2.25 |
||
DD&A ($/Boe) |
$16 – $17 |
1 Includes 20 - 25 percent non-drill capital |
2 Includes completions which are within the drilling joint venture with 40 percent of total well costs to EP Energy |
3 Includes completions which are within the drilling joint ventures in the Altamont program |
4 Severance taxes estimates are based off of current strip prices |
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 11:00 a.m. Eastern Time, 10:00 a.m. Central Time, on November 2, 2017, to discuss its third quarter financial and operational results and the senior leadership changes. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 8120184) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through December 2, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10112544).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment of debt, impairment charges, and other costs that affect comparability, including transition and severance costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS:
Quarter ended September 30, 2017 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(72) |
$ |
(0.29) | |||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
50 |
$ |
32 |
$ |
0.13 | |||||
Gain on extinguishment of debt |
(24) |
(15) |
(0.06) | ||||||||
Impairment charges |
1 |
— |
— | ||||||||
Valuation allowance on deferred tax assets |
24 |
0.10 | |||||||||
Total adjustments |
$ |
27 |
$ |
41 |
$ |
0.17 | |||||
Adjusted EPS |
$ |
(0.12) | |||||||||
Diluted weighted average shares |
246 |
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | |||
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. | |||
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the period presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), gains and losses on extinguishment of debt, gains and/or losses on sale of assets and impairment charges. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net loss to EBITDAX and Adjusted EBITDAX:
Quarter ended September 30, | |||||||
2017 |
2016 | ||||||
($ in millions, except equivalent volumes | |||||||
Net loss |
$ |
(72) |
$ |
(43) | |||
Income tax (benefit) expense |
(2) |
1 | |||||
Interest expense, net of capitalized interest |
80 |
74 | |||||
Depreciation, depletion and amortization |
118 |
132 | |||||
Exploration expense |
3 |
1 | |||||
EBITDAX |
127 |
165 | |||||
Mark-to-market on financial derivatives(1) |
23 |
(43) | |||||
Cash settlements and cash premiums on financial derivatives(2) |
27 |
145 | |||||
Non-cash portion of compensation expense(3) |
5 |
5 | |||||
Loss on sale of assets |
— |
4 | |||||
Gain on extinguishment of debt |
(24) |
(26) | |||||
Impairment charges |
1 |
— | |||||
Adjusted EBITDAX |
$ |
159 |
$ |
250 | |||
Total equivalent volumes (MBoe) |
7,456 |
7,326 | |||||
Adjusted EBITDAX Per Unit (MBoe)(4) |
$ |
21.40 |
$ |
34.18 |
(1) |
Represents the income statement impact of financial derivatives. | ||||
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | ||||
(3) |
Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. | ||||
(4) |
Adjusted EBITDAX Per Unit is based on actual total amounts rather than the rounded totals presented. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains and/or losses on sale of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans). We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to the operation of our assets. We exclude the non-cash portion of compensation expense, as we believe such adjustment allows investors to evaluate our costs against others in our industry and this item can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended September 30, | ||||||||||||||||
2017 |
2016 | |||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Oil and natural gas purchases |
$ |
— |
$ |
— |
$ |
2 |
$ |
0.25 |
||||||||
Transportation costs |
29 |
3.91 |
27 |
3.71 |
||||||||||||
Lease operating expense |
42 |
5.66 |
37 |
5.13 |
||||||||||||
General and administrative |
25 |
3.28 |
31 |
4.21 |
||||||||||||
Depreciation, depletion and amortization |
118 |
15.92 |
132 |
17.97 |
||||||||||||
Loss on sale of assets |
— |
— |
4 |
0.53 |
||||||||||||
Impairment charges |
1 |
0.09 |
— |
— |
||||||||||||
Exploration and other expense |
6 |
0.83 |
1 |
0.21 |
||||||||||||
Taxes, other than income taxes |
16 |
2.10 |
15 |
1.94 |
||||||||||||
Total operating expenses |
$ |
237 |
$ |
31.79 |
$ |
249 |
$ |
33.95 |
||||||||
Adjustments: |
||||||||||||||||
Depreciation, depletion and amortization |
$ |
(118) |
$ |
(15.92) |
$ |
(132) |
$ |
(17.97) |
||||||||
Impairment charges |
(1) |
(0.09) |
— |
— |
||||||||||||
Exploration expense |
(3) |
(0.40) |
(1) |
(0.21) |
||||||||||||
Loss on sale of assets |
— |
— |
(4) |
(0.53) |
||||||||||||
Non-cash portion of compensation expense(2) |
(5) |
(0.65) |
(5) |
(0.74) |
||||||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
$ |
110 |
$ |
14.73 |
$ |
107 |
$ |
14.50 |
||||||||
Total consolidated equivalent volumes (MBoe) |
7,456 |
7,326 |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. | ||||
(2) |
Amounts are excluded in the calculation of adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense under our long-term incentive programs adjusted for cash payments under these plans.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense:
Current Guidance | |||||||
Low |
High | ||||||
($/Boe) | |||||||
GAAP general and administrative expense |
$ |
3.35 |
$ |
3.50 |
|||
Less non-cash compensation expense |
0.45 |
0.50 |
|||||
Adjusted general and administrative expense |
$ |
2.90 |
$ |
3.00 |
EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted general and administrative expense is used by management and investors as additional information. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted general and administrative expense should not be used as an alternative to GAAP general and administrative expense. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reports-third-quarter-2017-results-on-track-with-2017-targets-announces-senior-leadership-changes-300547901.html
SOURCE EP Energy Corporation
HOUSTON, Oct. 30, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 11 a.m. Eastern Time, 10 a.m. Central Time, on Thursday, November 2, to discuss its third quarter 2017 financial and operational results. The company's third quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, November 1, 2017.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 8120184) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through Friday, December 1, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10112544). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-to-host-third-quarter-2017-results-webcast-on-november-2-300545911.html
SOURCE EP Energy Corporation
HOUSTON, Oct. 13, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today announced an update on its operations following Hurricane Harvey and reaffirmed the company's annual production and capital estimates for 2017.
As previously announced, EP Energy's producing and field facilities sustained no damage as a result of Hurricane Harvey and the company's drilling operations continued throughout the storm. A short-term reduction in the company's sales volumes resulted from temporary losses of downstream infrastructure and markets.
The third quarter storm impact to company production volumes was approximately 0.9 thousand barrels of equivalent production per day (MBoe/d), including 0.3 thousand barrels of oil production per day (MBo/d), in the Eagle Ford program. Consistent with previous guidance, the company expects total production of 81.0 MBoe/d, including 45.1 MBo/d for the third quarter 2017 despite the hurricane impacts.
The company's full year production remains on track. For 2017, the company expects total equivalent production volumes to range from 80.0 MBoe/d to 85.0 MBoe/d, including 46.0 MBo/d to 48.0 MBo/d which is also consistent with previous guidance. Total 2017 oil and gas capital expeditures are expected to remain in the range of $550 million to $600 million.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reaffirms-2017-production-outlook-and-provides-operational-impact-following-hurricane-harvey-300536229.html
SOURCE EP Energy Corporation
HOUSTON, Aug. 31, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today announced the company's Eagle Ford assets have not experienced any damage from weather relating to Hurricane Harvey. The local area only experienced a few inches of rain, which did not impair drilling or production operations.
"Our teams have performed well and operations have been conducted safely during the last week. We remain focused on the safety of all of our employees and the communities in which we operate," said Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation. "Production volume impacts were minimal during the storm. Looking ahead, we will continue to monitor the recovery of the Gulf Coast downstream infrastructure for potential impacts on market demand."
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reports-eagle-ford-operations-minimally-impacted-by-hurricane-harvey-300512603.html
SOURCE EP Energy Corporation
HOUSTON, Aug. 2, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported second quarter 2017 financial and operational results.
Second quarter 2017 Highlights
"Due to our strong operational performance in the quarter and year to date, we are maintaining our full year oil production guidance while lowering expected completion activities and capital," said Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation. "We improved capital efficiencies in all of our asset programs which helped offset cost inflation and reduce the maintenance capital levels needed to sustain production. In the Permian Basin, we increased activities in our Wolfcamp program in the quarter and expect to further increase activities and production in the second half of 2017 in that basin. During the quarter, we also entered into a new drilling joint venture in our Altamont program which increases capital efficiency and project returns. In June and July, we repurchased $157 million of high coupon debt at a discount and we remain focused on improving our financial position."
EP Energy reported a $(0.01) diluted net loss per share and a $(0.10) adjusted loss per share for the second quarter of 2017. Reported net loss was $3 million for the second quarter of 2017, down from $62 million net income in the second quarter of 2016. Adjusted EBITDAX for the second quarter of 2017 was $179 million, down from $256 million in the second quarter of 2016 due primarily to lower hedge settlements and lower gas volumes from the sale of the Haynesville gas asset in May 2016, partially offset by higher realized pricing on physical sales and lower operating costs in 2017.
Operating expenses for the second quarter of 2017 were $235 million, up from $127 million in the second quarter of 2016, or $30.46 per barrel of oil equivalent (Boe) for the second quarter of 2017 versus $16.47 per Boe in the second quarter of 2016. The second quarter of 2016 included an $82 million (or $10.77 per Boe) gain from the sale of the company's Haynesville gas assets. Adjusted cash operating costs were $103 million for the second quarter of 2017, down from $106 million in the second quarter of 2016. For the second quarter of 2017, adjusted cash operating costs per unit were $13.42 per Boe, down from $13.85 per Boe for the second quarter of 2016 due primarily to lower general and administrative costs, lower third party commodity purchases and higher production volumes.
Total capital expenditures in the second quarter of 2017 were $128 million. In the second quarter of 2017, the company completed 35 wells compared to 15 wells in the second quarter of 2016. Average daily oil production was 48.9 MBbls/d, up 8 percent from 45.1 MBbls/d in the second quarter of 2016, and up 4 percent from the first quarter of 2017. Oil production has grown each quarter since the third quarter of 2016. Total equivalent production was 84.9 thousand barrels of oil equivalent per day (MBoe/d), up from 84.5 MBoe/d in the same period last year, which included 6.3 MBoe/d from the Haynesville assets sold in May 2016.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
EP Energy continued to make progress improving its financial position and flexibility.
The company executed open-market repurchases of $56 million in June and an additional $101 million in July. In total, the $157 million of repurchases ($125 million of Notes maturing in 2020 and $32 million of Notes maturing in 2023) were completed for $118 million in cash or a price of 75 percent of face value. The company expects to reduce annualized interest expense by approximately $10 million as a result of these repurchases.
As previously announced, the company successfully completed its semi-annual borrowing base redetermination for its RBL Facility in April. The value was affirmed at $1.44 billion, and the company extended its 1st Lien debt to EBITDAX ratio covenant through the end of the first quarter of 2019 and reduced the ratio from 3.5x to 3.0x. As of June 30, 2017, the company's 1st Lien debt to EBITDAX ratio was approximately 0.5x.
EP Energy continues to prioritize balance sheet improvements and maintaining a strong liquidity position. The company ended the quarter with $4.0 billion of debt and $1.1 billion of liquidity, essentially flat to year end 2016.
Eagle Ford Program
In the second quarter of 2017, EP Energy completed 9 wells in its Eagle Ford program and produced 26.4 MBbls/d of oil, a 3 percent decrease compared with the second quarter of 2016. However, volumes were up 10 percent from the first quarter of 2017. Total equivalent production for the second quarter of 2017 was 41.5 MBoe/d.
In the quarter, the company improved operational efficiencies and reduced base production decline rates with a continued focus on base production optimization.
EP Energy currently has one drilling rig in Eagle Ford and remains focused on continuing to improve program returns and operational efficiencies while running one drilling rig for the remainder of 2017.
Wolfcamp Program
EP Energy continued to grow activity in its Wolfcamp program. In the second quarter of 2017, the company completed 21 gross wells (10.5 net wells) and produced 9.9 MBbls/d of oil, a 46 percent increase compared with the second quarter of 2016. Total equivalent production for the second quarter of 2017 was 25.4 MBoe/d.
Production volumes were down compared to the first quarter of 2017 due to a higher percentage of 50 percent joint venture wells, the impact of higher royalties from higher oil prices and timing of well completions within the quarter.
EP Energy currently has two drilling rigs in Wolfcamp and expects to increase well completions and production in the second half of the year while maintaining two drilling rigs for the remainder of 2017.
Altamont Program
In the second quarter of 2017, EP Energy completed 5 gross wells (3 net wells) in its Altamont program and produced 12.6 MBbls/d of oil, a 15 percent increase compared with second quarter of 2016. Total equivalent production for the second quarter of 2017 was 18.0 MBoe/d, up 16 percent from the second quarter of 2016.
In the second quarter of 2017, realized pricing for Altamont production volumes was 95 percent of WTI as a result of improved contract terms and local market conditions as compared to 89 percent of WTI in the same period in 2016.
EP Energy has two drilling rigs in Altamont and continues to benefit from its successful recompletion program. During the second quarter, the company entered into a new 60 well drilling joint venture program which increased program returns. For the second half of 2017, the company expects to run two joint venture drilling rigs and continue its recompletion program.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program which provides continued commodity price protection. In the second quarter of 2017, the company realized $31 million of settlements on its financial derivatives.
During the second quarter, the company enhanced its price protection by adding 2018 oil hedges and 2019 natural gas hedges. A summary of the company's current open hedge positions including its most recent transactions is listed below:
2017 |
2018 |
2019 |
|||||||||||
Total Fixed Price Hedges |
|||||||||||||
Oil volumes (MMBbls)(1) |
5.0 |
8.9 |
— |
||||||||||
Average floor price ($/Bbl) |
$ |
60.34 |
$ |
60.00 |
$ |
— |
|||||||
Natural Gas volumes (TBtu) |
17.5 |
25.6 |
7.3 |
||||||||||
Average floor price ($/MMBtu) |
$ |
3.28 |
$ |
3.04 |
$ |
2.97 |
Note: Positions are as of August 1, 2017 (Contract months: July 2017 - Forward). |
At June 30, 2017, the mark-to-market value of the company's hedge contracts was approximately $114 million.
2017 Outlook
In its updated 2017 outlook, EP Energy expects to maintain its previous full year oil production guidance while lowering completion activities and capital expenditures. The company also improved its outlook for unit cash operating costs in 2017 as a result of increased operational efficiencies.
The table below summarizes the company's current operational and financial guidance for 2017 compared with previously announced guidance ranges.
Previous |
Current |
||||
Oil production (MBbls/d) |
45 – 49 |
46 – 48 |
|||
Total production (MBoe/d) |
75 – 82 |
80 – 85 |
|||
Oil & Gas capital ($ million)1 |
|||||
Wolfcamp |
$245 – $325 |
$250 – $300 |
|||
Eagle Ford |
$260 – $270 |
~$200 |
|||
Altamont |
$125 – $135 |
~$100 |
|||
Total capital program ($ million) |
$630 – $730 |
$550 – $600 |
|||
Gross well completions |
|||||
Wolfcamp2 |
90 – 105 |
80 – 100 |
|||
Eagle Ford |
~60 |
~50 |
|||
Altamont3 |
~25 |
~30 |
|||
Total |
175 – 190 |
160 – 180 |
|||
GAAP general and administration expense ($/Boe) |
$3.95 – $4.35 |
$3.35 – $3.50 |
|||
Lease operating expense ($/Boe) |
$5.85 – $6.35 |
$5.50 – $5.85 |
|||
Adjusted general and administration expense ($/Boe) |
$3.15 – $3.40 |
$2.90 – $3.00 |
|||
Transportation and commodity purchases ($/Boe) |
$3.90 – $4.50 |
$3.85 – $4.25 |
|||
Taxes, other than income ($/Boe)4 |
$2.70 – $2.85 |
$2.10 – $2.25 |
|||
DD&A ($/Boe) |
$16 – $17 |
$16 – $17 |
1 Includes 20 - 25 percent non-drill capital |
2 Includes completions which are within the DrillCo joint venture with 40 percent of total well costs to EP Energy |
3 Includes completions which are within the drilling joint ventures in the Altamont program |
4 Severance taxes estimates are based off of current strip prices |
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on August 3, 2017, to discuss its second quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 5555441) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through September 3, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10110091).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment of debt, impairment charges, and other costs that affect comparability, including transition and severance costs and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS:
Quarter ended June 30, 2017 | ||||||||||||
Pre Tax |
After Tax |
Diluted | ||||||||||
($ in millions, except earnings per share amounts) | ||||||||||||
Net loss |
$ |
(3) |
$ |
(0.01) |
||||||||
Adjustments(2) |
||||||||||||
Impact of financial derivatives(3) |
$ |
(14) |
$ |
(9) |
$ |
(0.04) |
||||||
Gain on extinguishment of debt |
(13) |
(8) |
(0.04) |
|||||||||
Impairment charges |
1 |
— |
— |
|||||||||
Valuation allowance on deferred tax assets |
(3) |
(0.01) |
||||||||||
Total adjustments |
$ |
(26) |
$ |
(20) |
$ |
(0.09) |
||||||
Adjusted EPS |
$ |
(0.10) |
||||||||||
Diluted weighted average shares |
246 |
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. | |||
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. | |||
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the period presented. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, severance and other costs that affect comparability, gains and losses on extinguishment of debt, gains and/or losses on sale of assets and impairment charges. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net (loss) income to EBITDAX and Adjusted EBITDAX:
Quarter ended June 30, | |||||||
2017 |
2016 | ||||||
($ in millions, except equivalent volumes | |||||||
Net (loss) income |
$ |
(3) |
$ |
62 |
|||
Income tax benefit |
(5) |
— |
|||||
Interest expense, net of capitalized interest |
82 |
73 |
|||||
Depreciation, depletion and amortization |
124 |
97 |
|||||
Exploration expense |
1 |
1 |
|||||
EBITDAX |
199 |
233 |
|||||
Mark-to-market on financial derivatives(1) |
(45) |
105 |
|||||
Cash settlements and cash premiums on financial derivatives(2) |
31 |
157 |
|||||
Non-cash portion of compensation expense(3) |
6 |
3 |
|||||
Transition, severance and other costs(4) |
— |
2 |
|||||
Gain on sale of assets |
— |
(82) |
|||||
Gain on extinguishment of debt |
(13) |
(162) |
|||||
Impairment charges |
1 |
— |
|||||
Adjusted EBITDAX |
$ |
179 |
$ |
256 |
|||
Total equivalent volumes (MBoe) |
7,730 |
7,691 |
|||||
Adjusted EBITDAX Per Unit (MBoe)(5) |
$ |
23.19 |
$ |
33.27 |
(1) |
Represents the income statement impact of financial derivatives. | |||
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. | |||
(3) |
Non-cash portion of compensation expense represents compensation expense (net of forfeitures) under long-term incentive programs adjusted for cash payments made under these plans. | |||
(4) |
Reflects transition and severance costs related to workforce reductions. | |||
(5) |
Adjusted EBITDAX Per Unit is based on actual total amounts rather than the rounded totals presented. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains and/or losses on sale of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, severance and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to the operation of our assets. We exclude the non-cash portion of compensation expense as well as transition, severance and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and these items can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended June 30, | ||||||||||||||||
2017 |
2016 | |||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Oil and natural gas purchases |
$ |
1 |
$ |
0.09 |
$ |
3 |
$ |
0.38 |
||||||||
Transportation costs |
28 |
3.66 |
24 |
3.19 |
||||||||||||
Lease operating expense |
39 |
5.07 |
38 |
4.93 |
||||||||||||
General and administrative |
26 |
3.43 |
32 |
4.20 |
||||||||||||
Depreciation, depletion and amortization |
124 |
15.99 |
97 |
12.67 |
||||||||||||
Gain on sale of assets |
— |
— |
(82) |
(10.77) |
||||||||||||
Impairment charges |
1 |
0.05 |
— |
— |
||||||||||||
Exploration and other expense |
1 |
0.20 |
1 |
0.12 |
||||||||||||
Taxes, other than income taxes |
15 |
1.97 |
14 |
1.75 |
||||||||||||
Total operating expenses |
$ |
235 |
$ |
30.46 |
$ |
127 |
$ |
16.47 |
||||||||
Adjustments: |
||||||||||||||||
Depreciation, depletion and amortization |
$ |
(124) |
$ |
(15.99) |
$ |
(97) |
$ |
(12.67) |
||||||||
Impairment charges |
(1) |
(0.05) |
— |
— |
||||||||||||
Exploration expense |
(1) |
(0.20) |
(1) |
(0.12) |
||||||||||||
Gain on sale of assets |
— |
— |
82 |
10.77 |
||||||||||||
Non-cash portion of compensation expense(2) |
(6) |
(0.80) |
(3) |
(0.35) |
||||||||||||
Transition, severance and other costs |
— |
— |
(2) |
(0.25) |
||||||||||||
Adjusted cash operating costs and per-unit adjusted |
$ |
103 |
$ |
13.42 |
$ |
106 |
$ |
13.85 |
||||||||
Total consolidated equivalent volumes (MBoe) |
7,730 |
7,691 |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. | |||
(2) |
These amounts are reported in GAAP general and administrative expense and excluded from adjusted general and administrative expense. |
Adjusted general and administrative expenses are defined as general and administrative expenses excluding the non-cash portion of compensation expense which represents compensation expense under our long-term incentive programs adjusted for cash payments under these plans.
Below is a reconciliation of our GAAP general and administrative expense to non-GAAP adjusted general and administrative expense:
Previous Guidance |
Current Guidance | ||||||||||||||
Low |
High |
Low |
High | ||||||||||||
($/Boe) | |||||||||||||||
GAAP general and administrative expense |
$ |
3.95 |
$ |
4.35 |
$ |
3.35 |
$ |
3.50 |
|||||||
Less non-cash compensation expense |
0.80 |
0.95 |
0.45 |
0.50 |
|||||||||||
Adjusted general and administrative expense |
$ |
3.15 |
$ |
3.40 |
$ |
2.90 |
$ |
3.00 |
EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. Adjusted general and administrative expense is used by management and investors as additional information. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted general and administrative expense should not be used as an alternative to GAAP general and administrative expense. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Adjusted Cash Operating Costs, and Adjusted general and administrative expense should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-reports-second-quarter-2017-results-ahead-of-expectations-300498694.html
SOURCE EP Energy Corporation
HOUSTON, July 28, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Thursday, August 3, to discuss its second quarter 2017 financial and operational results. The company's second quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, August 2, 2017.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 5555441) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through Friday, September 1, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10110091). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
View original content with multimedia:http://www.prnewswire.com/news-releases/ep-energy-to-host-second-quarter-2017-results-webcast-on-august-3-300495974.html
SOURCE EP Energy Corporation
HOUSTON and SAN ANTONIO, May 24, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) and Tesoro Corporation (NYSE: TSO) announced the formation of a drilling joint venture, through respective subsidiaries, to fund oil and natural gas development in EP Energy's Altamont program located in the Uinta Basin of Utah. Additionally, EP Energy and Tesoro signed a multi-year Crude Oil Supply Agreement for yellow and black waxy crude oil to supply Tesoro's Salt Lake City Refinery.
Drilling Joint Venture Highlights
Tesoro and EP Energy also entered into a Crude Oil Supply Agreement, through which Tesoro will purchase all of the oil produced through the drilling joint venture, along with additional waxy crude oil produced by EP Energy in the Uinta Basin. This oil will provide assured supply of local crude oil for Tesoro's Salt Lake City Refinery.
"In the Altamont field we have a deep inventory of high-return drilling opportunities. This joint venture will enable us to significantly increase the well-level returns and capital efficiency of our program," said Brent Smolik, Chairman, President, and Chief Executive Officer of EP Energy Corporation. "We plan to keep two rigs active in the Uinta Basin and look forward to building a long-term relationship with Tesoro, an in-basin refinery partner."
"This agreement with EP Energy is an important step to further enhance our integrated value chain in the Rockies by supporting the growth of waxy crude oil production in the Uinta Basin, and allowing us to secure additional supply of this advantaged crude oil to further optimize the operation of our Salt Lake City Refinery," said Greg Goff, Chairman, President and CEO of Tesoro. "We believe this investment in crude oil production in Utah is good for our shareholders, our communities and for the State of Utah as it supports economic development in the region."
The first wells under the joint venture are expected to begin production in July 2017. EP Energy's average working interest in the joint venture wells is currently approximately 80 percent.
EP Energy did not change its 2017 guidance for the new drilling venture; however the company expects to update its full year 2017 outlook mid-year.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North American. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
About Tesoro
Tesoro Corporation, a Fortune 100 company, is an independent refiner and marketer of petroleum products. Tesoro, through its subsidiaries, operates seven refineries in the western United States with a combined capacity of over 895,000 barrels per day and ownership in a logistics business, which includes an interest in Tesoro Logistics LP (NYSE: TLLP) and ownership of its general partner. Tesoro's retail-marketing system includes over 2,500 retail stations under the ARCO®, Shell®, Exxon®, Mobil®, USA Gasoline(TM), Rebel(TM) and Tesoro® brands.
EPE: Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward‐looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; changes in commodity prices and basis differentials for oil and natural gas; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; political and currency risks associated with international operations of the company; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward‐looking statements made herein or any other forward‐looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
TSO: Forward-Looking Statements
This release contains "forward-looking" statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, including without limitation statements concerning: Tesoro's operational, financial and growth strategies, its ability to successfully effect those strategies and the expected timing and results thereof; statements regarding Tesoro's agreement with EP Energy, the terms thereunder, and the expected benefits thereof, including benefits to Tesoro's business, shareholders, communities and the State of Utah; and expected timing of well production. For more information concerning factors that could affect these statements, see Tesoro's annual report on Form 10-K, quarterly reports on Form 10-Q, and other public filings and press releases, available at www.tsocorp.com. Tesoro undertakes no obligation to revise or update any forward-looking statements as a result of new information, future events or otherwise.
EPE Contact:
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Tesoro Contacts:
Investors: Sam Ramraj, Vice President, Investor Relations, (210) 626-4757
Media: Tesoro Media Relations, media@tsocorp.com, (210) 626-7702
SOURCE EP Energy Corporation; Tesoro Corporation
HOUSTON, May 3, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported first quarter 2017 financial and operational results.
First quarter 2017 Highlights
"We came out of the gates quickly in the first quarter and built on the operational and financial successes of 2016," said Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation. "During the first quarter, we increased completion activities, improved efficiencies in our asset programs which offset inflation, and grew oil volumes for the second quarter in a row. We've continued to increase financial flexibility since the beginning of the year by extending debt maturities by $940 million to 2025, increasing liquidity, and enhancing our RBL Facility. We also launched a Wolfcamp drilling joint venture and increased drilling activity in a capital efficient manner in that strategically important asset."
EP Energy reported a $0.19 diluted net loss per share and a $0.10 adjusted loss per share (EPS) for the first quarter of 2017. Reported net loss was $47 million for the first quarter of 2017, down from $94 million net income in the first quarter of 2016. Adjusted EBITDAX for the first quarter of 2017 was $172 million, down from $278 million in the first quarter of 2016, due primarily to lower hedge settlements and lower production volumes, partially offset by higher realized pricing on physical sales and lower operating costs.
Operating expenses for the first quarter of 2017 were $238 million, down from $242 million in the first quarter of 2016. Adjusted cash operating costs were $113 million for the first quarter of 2017, down from $116 million in the first quarter of 2016. The improvement in 2017 is primarily due to lower LOE, transportation and third party commodity purchases, and general and administrative costs, partially offset by higher production taxes due to higher price realizations. For the first quarter of 2017, adjusted cash operating costs were $15.16 per barrel of oil equivalent (Boe), up from $12.28 per Boe for the first quarter of 2016, due primarily to lower production volumes largely driven by the Haynesville asset divestiture in 2016 and higher production taxes associated with higher price realizations. However, for the first quarter of 2017, adjusted cash operating costs were below the low end of the company's guidance range.
Total capital expenditures in the first quarter of 2017 were $152 million. In the first quarter of 2017, the company completed 44 wells compared to 23 wells in the first quarter of 2016. Average daily oil production was 46.9 MBbls/d, down 8 percent from 50.8 MBbls/d in the first quarter of 2016, but up 3 percent from the fourth quarter of 2016. Oil production has been steadily growing since the third quarter of 2016. Total equivalent production was 82.5 thousand barrels of oil equivalent per day (MBoe/d), down from 104.0 MBoe/d in the same period last year. The reduction in equivalent volumes included a 111 million cubic feet per day (18.6 MBoe/d) reduction attributed to the sale of the company's Haynesville Shale assets in May 2016.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
EP Energy continued to make progress improving its financial position and flexibility. During the quarter, capital expenditures were essentially in-line with operating cash flow, and the company extended debt maturities and increased available liquidity. The company ended the quarter with $3.9 billion of debt, essentially flat to end of the year 2016, and $1.2 billion of liquidity, up from $1.1 billion at year-end 2016.
The company maintains a RBL Facility which is supported by reserves on its long-lived assets. In April, the company successfully completed its semi-annual borrowing base redetermination. The value was affirmed at $1.44 billion. In addition, the company obtained covenant relief by extending its 1st Lien debt to EBITDAX ratio covenant through the end of the first quarter of 2019. Also, as part of the agreement, the 1st Lien debt to EBITDAX ratio covenant was reduced from 3.5x to 3.0x, and the company paid an amendment fee of approximately $1 million. As of March 31, 2017, the company's 1st Lien debt to EBITDAX ratio was 0.28x.
EP Energy continues to prioritize balance sheet improvements and maintaining a strong liquidity position.
Eagle Ford Program
In the first quarter of 2017, EP Energy increased activities in its Eagle Ford program and completed 30 wells compared to 16 wells in the first quarter of 2016 and produced 23.9 MBbls/d of oil, a 26 percent decrease compared with the first quarter of 2016. However, volumes were up 8 percent from the fourth quarter of 2016. The oil production decline from the first quarter of 2016 was primarily due to significantly lower activity levels in 2016. Total equivalent production for the first quarter of 2017 was 37.7 MBoe/d.
In the quarter, the company also improved operational efficiencies and reduced production decline rates with a continued focus on production optimization. EP Energy currently has one drilling rig and one frac crew active in the Eagle Ford and remains focused on continuing to improve well performance and operational efficiencies.
Wolfcamp Program
EP Energy continued to grow production volumes in its Wolfcamp program. In the first quarter of 2017, the company completed 11 wells and produced 11.1 MBbls/d of oil, a 59 percent increase compared with the first quarter of 2016. Total equivalent production for the first quarter of 2017 was 27.5 MBoe/d, up slightly from the fourth quarter of 2016.
Production volumes were up slightly compared to the fourth quarter of 2016 despite higher net royalties, a lower number of well completions in the first quarter, and the start of its drilling joint venture which reduced the working interest on new wells included in the joint venture to 50 percent.
The company currently has two drilling rigs and two frac crews active in the Wolfcamp. The company expects to increase capital allocation to the Wolfcamp program, increasing completions each quarter throughout the remainder of the year.
Altamont Program
In the first quarter of 2017, EP Energy completed three wells in its Altamont program and produced 11.9 MBbls/d of oil, a 4 percent increase compared with first quarter of 2016. Altamont total equivalent production for the first quarter of 2017 was 17.3 MBoe/d, roughly flat to the fourth quarter of 2016.
EP Energy has two drilling rigs active in the Altamont and continues to benefit from its successful recompletion program. During the first quarter, the company continued its 12-well drilling joint venture program, which increased program returns. As a result of the program's success, the company is currently pursuing additional drilling joint venture opportunities.
In the first quarter of 2017, realized pricing for Altamont production volumes improved significantly relative to WTI as a result of improved contract terms and local market conditions as compared to the same period in 2016.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program which provides substantial commodity price protection. In the first quarter of 2017, the company realized $28 million of settlements on its financial derivatives.
Recently, the company enhanced its price protection with additional 2018 oil hedges.
A summary of the company's current open hedge positions including its most recent transactions is listed below:
2017 |
2018 |
||||||||
Total Fixed Price Hedges |
|||||||||
Oil volumes (MMBbls)(1) |
7.7 |
8.9 |
|||||||
Average floor price ($/Bbl) |
$ |
60.52 |
$ |
60.00 |
|||||
Natural gas volumes (TBtu) |
26.1 |
18.3 |
|||||||
Average floor price ($/MMBtu) |
$ |
3.28 |
$ |
3.07 |
Note: Positions are as of May 2, 2017 (Contract months: April 2017 - Forward). |
(1) 2017 positions include WTI three way collars of 6.7 MMBbls and 2018 positions include WTI three way collars of 8.9 MMBbls. |
At March 31, 2017, the mark-to-market value of the company's hedge contracts was approximately $100 million.
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 11:00 a.m. Eastern Time, 10:00 a.m. Central Time, on May 4, 2017, to discuss its first quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 0291439) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through June 2, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10105466).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment of debt and other costs that affect comparability, including transition and restructuring charges and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS:
Quarter ended March 31, 2017 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(47) |
$ |
(0.19) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
(42) |
$ |
(27) |
$ |
(0.11) |
|||||
Loss on extinguishment of debt |
53 |
34 |
0.14 |
||||||||
Valuation allowance on deferred tax assets |
15 |
0.06 |
|||||||||
Total adjustments |
$ |
11 |
$ |
22 |
$ |
0.09 |
|||||
Adjusted EPS |
$ |
(0.10) |
|||||||||
Diluted weighted average shares(4) |
245 |
||||||||||
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. |
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the period presented. |
(4) |
Diluted shares include certain restricted stock and performance unit awards. |
Free Cash Flow is defined as net cash provided by operating activities less cash paid for capital expenditures. Below is a reconciliation of our net cash provided by operating activities to Free Cash Flow:
Quarter ended |
||||
($ in millions) |
||||
Net cash provided by operating activities |
$ |
117 |
||
Cash paid for capital expenditures |
119 |
|||
Free Cash Flow |
$ |
(2) |
||
Net cash used in investing activities |
$ |
(119) |
||
Net cash provided by financing activities |
$ |
17 |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under these plans), transition, restructuring and other costs that affect comparability and gains and losses on extinguishment of debt. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net (loss) income to EBITDAX and Adjusted EBITDAX:
Quarter ended March 31, | ||||||||
2017 |
2016 | |||||||
($ in millions, except equivalent volumes | ||||||||
Net (loss) income |
$ |
(47) |
$ |
94 |
||||
Income tax expense |
— |
— |
||||||
Interest expense, net of capitalized interest |
83 |
84 |
||||||
Depreciation, depletion and amortization |
126 |
113 |
||||||
Exploration expense |
3 |
1 |
||||||
EBITDAX |
165 |
292 |
||||||
Mark-to-market on financial derivatives(1) |
(70) |
(42) |
||||||
Cash settlements and cash premiums on financial derivatives(2) |
28 |
212 |
||||||
Non-cash portion of compensation expense(3) |
(4) |
4 |
||||||
Transition, restructuring and other costs(4) |
— |
8 |
||||||
Loss (gain) on extinguishment of debt |
53 |
(196) |
||||||
Adjusted EBITDAX |
$ |
172 |
$ |
278 |
||||
Total equivalent volumes (MBoe) |
7,426 |
9,466 |
||||||
Adjusted EBITDAX Per Unit (MBoe)(5) |
$ |
23.10 |
$ |
29.37 |
||||
(1) |
Represents the income statement impact of financial derivatives. |
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(3) |
Cash payments for the quarter ended March 31, 2017 and 2016 were approximately $4 million and less than $1 million, respectively. |
(4) |
Reflects transition and severance costs related to workforce reductions. |
(5) |
Adjusted EBITDAX Per Unit is based on actual total amounts rather than the rounded totals presented. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, restructuring and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. We exclude the non-cash portion of compensation expense as well as transition, restructuring and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and these items can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended March 31, | ||||||||||||
2017 |
2016 | |||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||
($ in millions, except per unit costs) | ||||||||||||
Oil and natural gas purchases |
||||||||||||
$ |
1 |
$ |
0.15 |
$ |
4 |
$ |
0.46 | |||||
Transportation costs |
29 |
3.84 |
30 |
3.11 | ||||||||
Lease operating expense |
40 |
5.37 |
42 |
4.38 | ||||||||
General and administrative |
20 |
2.66 |
38 |
4.04 | ||||||||
Depreciation, depletion and amortization |
126 |
16.99 |
113 |
11.94 | ||||||||
Exploration and other expense |
3 |
0.39 |
1 |
0.13 | ||||||||
Taxes, other than income taxes |
19 |
2.61 |
14 |
1.55 | ||||||||
Total operating expenses |
$ |
238 |
$ |
32.01 |
$ |
242 |
$ |
25.61 | ||||
Adjustments: |
||||||||||||
Depreciation, depletion and amortization |
$ |
(126) |
$ |
(16.99) |
$ |
(113) |
$ |
(11.94) | ||||
Exploration expense |
(3) |
(0.39) |
(1) |
(0.13) | ||||||||
Non-cash portion of compensation expense |
4 |
0.53 |
(4) |
(0.43) | ||||||||
Transition, restructuring and other costs |
— |
— |
(8) |
(0.83) | ||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
$ |
113 |
$ |
15.16 |
$ |
116 |
$ |
12.28 | ||||
Total consolidated equivalent volumes (MBoe) |
7,426 |
9,466 | ||||||||||
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Free Cash Flow is used by management and we believe provides investors with useful information for analysis of the company's ability to internally fund capital expenditures and to service or incur additional debt. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Free Cash Flow should not be used as an alternative to operating or investing cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
SOURCE EP Energy Corporation
HOUSTON, April 25, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 11 a.m. Eastern Time, 10 a.m. Central Time, on Thursday, May 4, to discuss its first quarter 2017 financial and operational results. The company's first quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, May 3, 2017.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 0291439) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through Friday, June 2, 2017 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID#10105466). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas in North America. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
SOURCE EP Energy Corporation
HOUSTON, March 1, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported fourth quarter and year-end 2016 financial and operational results for the company.
Key highlights include:
2016 Full Year Results
2016 Proved Reserves and Future Drilling Inventory
2017 Outlook
"In 2016 our teams executed well and successfully increased efficiencies, lowered costs and improved well performance in all asset areas," said Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation. "We reduced debt by $1 billion and significantly extended debt maturities. We also generated significant free cash flow in 2016 and increased liquidity in the second half of the year. Looking ahead, we are shifting our focus to growth, driven by our Permian Basin Wolfcamp asset, while maintaining our focus on balance sheet improvement. So, we enter 2017 much better positioned to capitalize on our high quality assets."
1 Percent hedged based on midpoint of 2017 guidance
2016 Financial Results
Fourth Quarter 2016
For the quarter ended December 31, 2016, EP Energy reported a $0.57 diluted net loss per share and $0.12 adjusted earnings per share (Adjusted EPS). The reported net loss for the fourth quarter of 2016 was $140 million, down from a $3,731 million net loss in the same 2015 period. The 2015 period included an after tax impairment of $2,755 million. Adjusted EBITDAX for the fourth quarter 2016 was $255 million, down from $425 million in the fourth quarter of 2015, due primarily to lower oil and natural gas production volumes and lower realized prices, including hedge impacts, partially offset by lower operating costs.
The company ended the year with fourth quarter operating expenses of $247 million, down from $4,688 million in the fourth quarter of 2015. The 2015 period included the before tax effects of the impairment of $4,299 million. Adjusted cash operating costs were $111 million for the fourth quarter 2016, down from $132 million in the same 2015 period. Adjusted cash operating costs were $14.80 per barrel of oil equivalent (Boe) for the fourth quarter 2016, up from $12.79 per Boe in the same 2015 period due to lower production volumes in 2016.
Full Year 2016
For the year ended December 31, 2016, EP Energy reported an $0.11 diluted net loss per share and Adjusted EPS of $0.62. Reported net loss was $27 million for the year 2016, down from $3,748 million in the same 2015 period. The 2015 period included after tax impairment charges of $2,755 million. Adjusted EBITDAX for the year 2016 was $1,039 million, down from $1,641 million in 2015 due primarily to lower production volumes and lower realized pricing, including hedges, partially offset by lower operating costs for the year.
Total operating expenses for the year ended December 31, 2016 were $865 million, down from $5,863 million in the same 2015 period. The 2015 period included the before tax effects of the impairment of $4,299 million. Adjusted cash operating costs were $440 million for the year 2016, down from $542 million in the same 2015 period. In addition, adjusted cash operating costs were $13.77 per Boe for the year 2016, up slightly from $13.56 per Boe in the same 2015 period due primarily to lower production volumes in 2016.
2016 capital expenditures were $488 million, down from $1,324 million in the same period 2015. In 2016 the company completed 98 wells, which was about half as many as EP Energy completed in 2015. Beginning in the second half of 2016, the company focused much of its investment in the Wolfcamp program. In 2016, the company spent $233 million in the Wolfcamp program, $175 million in the Eagle Ford program and $76 million in the Altamont program.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Financial Position and Liquidity
During the year 2016, EP Energy accomplished several significant milestones which improved the company's financial position. The company successfully reduced its debt by approximately $1 billion, utilizing free cash flow from operations and asset sales proceeds to conduct opportunistic open market repurchases of its debt at a discount and partially repay amounts outstanding under its reserve-based loan facility (RBL Facility).
At December 31, 2016, EP Energy's balance sheet included approximately $20 million of cash and cash equivalents and $3.9 billion of total debt. In addition, EP Energy successfully exchanged nearly all of its term loans due 2018 and 2019 for new term loans with an extended maturity in 2021, which eliminated the potential springing maturity of the RBL Facility in 2017. The company has no significant near-term debt maturities with the RBL facility maturing in May 2019 and the next note maturing in 2020.
For the year ended December 31, 2016, cash flow from operations was $784 million and cash capital expenditures were $533 million. In 2016, EP Energy generated $251 million of positive free cash flow.
EP Energy maintains a significant liquidity position of approximately $1.1 billion at year-end 2016, which is supported by the company's RBL Facility.
Additionally, in February 2017 the company issued $1 billion of notes due in 2025, to repay, in full, the $580 million notes due 2021, repurchase $250 million of notes due 2020 in the open market, and repay $111 million of the amounts outstanding under its RBL Facility.
Balance sheet improvement and the extension of its liquidity position remain priorities for the company going forward.
Operations
For the year ended December 31, 2016, average daily production was 87.6 MBoe/d, including 46.6 MBbls/d of oil. Fourth quarter 2016 average daily production was 82.5 MBoe/d, including 45.7 MBbls/d of oil.
During the fourth quarter and the second half of 2016, the company increased its completion activity. As a result, the fourth quarter reflected a return to sequential quarterly production growth in all commodities.
Wolfcamp Program
In 2016, the company completed 44 wells in its Wolfcamp program and produced 21.4 MBoe/d, an 8 percent increase from 2015. Total completions in 2016 were up from 36 in 2015, a 22 percent increase. In the fourth quarter of 2016, the company completed 21 wells, up from one completed well in the same 2015 period, and produced 27.4 MBoe/d, a 29 percent increase from the fourth quarter of 2015.
Total well costs in the Wolfcamp program averaged $4.6 million in 2016 which was approximately 13 percent lower than 2015 average well costs of $5.3 million. This cost reduction was realized even as the company applied enhanced completion designs with longer laterals in 2016.
Also in 2016, EP Energy amended its existing development agreement with its royalty owner, University Lands (UL). This amendment provided the company flexibility to extend its leasehold timeframe to 2021, and most importantly added a sliding scale royalty framework that improves well returns in the current price environment. Coupled with the recently announced joint venture in the Wolfcamp, these actions served to significantly increase the value and return profile of the Wolfcamp asset.
Eagle Ford Program
In 2016, the company completed 39 wells in its Eagle Ford program and production was 43.5 MBoe/d, a 25 percent decrease from 2015. Total completions in 2016 were down from 118 in 2015, a 67 percent decrease. During the fourth quarter of 2016, the company completed five wells and produced 37.7 MBoe/d, a 33 percent decrease from the fourth quarter of 2015.
EP Energy continued to reduce well costs in its Eagle Ford program. The average 2016 well cost was approximately $4.2 million, almost 28 percent lower than 2015 average well cost of $5.8 million.
The company continued to execute efficiently in the Eagle Ford in 2016. EP Energy has one rig currently running with the expectation of increasing completion activity.
Altamont Program
The company continued to efficiently develop its Altamont program, with the highest returns achieved in its recompletion program. In 2016, the company completed 15 new wells and performed 52 recompletions. Full year production was 16.5 MBoe/d, 4 percent lower than 2015. In the fourth quarter 2016, the company completed four wells and had production volumes of 17.4 MBoe/d.
The company is continuing to benefit from improved realized pricing relative to WTI oil prices. Along with these higher price realizations, the company also realized higher returns with its drilling joint venture.
Hedge Program Update
In 2016, EP Energy realized $639 million from settlements on financial derivatives. At year-end 2016, the MTM value of the company's hedge positions was approximately $57 million. For 2017, EP Energy has effectively hedged approximately 75 percent of its expected oil production at an average price of $61.66 per barrel, and hedged approximately 76 percent of its expected natural gas production at an average price of $3.28 per MMBtu.
A summary of the company's 2017 and 2018 hedge positions is listed below: | |||||||
2017 |
2018 | ||||||
Total Fixed Price Hedges |
|||||||
Oil volumes (MMBbls) |
12.8 |
3.3 |
|||||
Average floor price ($/Bbl) |
$ |
61.66 |
$ |
60.00 |
|||
Natural gas volumes (TBtu) |
32.0 |
11.0 |
|||||
Average floor prices ($/MMBtu) |
$ |
3.28 |
$ |
3.11 |
Note: Positions are as of February 27, 2017 (Contract months: January 2017 - Forward) and the table includes WTI three-way collars of 8.8 MMBbls and 3.3 MMBbls in 2017 and 2018, respectively. |
2016 Proved Reserves
EP Energy's proved oil and natural gas reserves were 432.4 MMBoe as of December 31, 2016, a 21 percent decrease compared to proved reserves at December 31, 2015 of 546.0 MMBoe. Proved developed reserves in 2016 were 47 percent of total proved reserves and 53 percent oil.
2016 proved reserves were lower than 2015 due to the Haynesville asset divestiture, lower average SEC prices, and the impact of the SEC's five-year development rule after our reduction in estimated capital in the company's long-range development plan.
The company operates 91 percent of its producing wells and has operational control over approximately 98 percent of its drilling inventory as of December 31, 2016.
The SEC first-day-of-the-month 12-month average prices for reserves as of December 31, 2016 were $42.75 per Bbl for oil, $2.48 per MMBtu for natural gas and $16.47 per Bbl for NGL, down from $50.28 per Bbl for oil, $2.59 per MMBtu for natural gas and $16.64 per Bbl for NGL in the prior 12-month period.
Future Drilling Inventory
At year-end 2016, EP Energy's estimated future drilling inventory, which includes proved undeveloped reserves and unproven resources, totaled 5,156 identified locations — 894 in the Eagle Ford, 2,937 in the Wolfcamp, and 1,325 in the Altamont.
2017 Outlook
2017 Capital Program
In 2017, EP Energy expects capital spending to range from $630 million to $730 million. The company maintains flexibility with regard to its spending range which is driven by the timing of an additional drilling rig in its Wolfcamp program.
Equivalent production in 2017 is expected to range from 75 MBoe/d to 82 MBoe/d with 45 MBbls/d to 49 MBbls/d of oil production. The company expects to grow Wolfcamp production, primarily in the second half of 2017, while holding Eagle Ford and Altamont production volumes flat from the second half of 2016.
Going forward, EP Energy expects to allocate excess cash flow generated by its Eagle Ford and Altamont programs to provide funds for its growing Wolfcamp program.
Operations
For the full year 2017, the company expects to complete 175 to 190 gross wells, with the majority in its Wolfcamp program in the Permian Basin.
In its Wolfcamp program, the company is expanding its development across Reagan and Crockett counties in each of the A, B and C benches. In 2017, the company expects to have two joint venture drilling rigs active for the full year, and plans to add a third drilling rig at mid-year. The company plans to drill longer laterals in 2017, with average lateral lengths greater than 9,000 feet, and average well cost of approximately $4.9 million, compared with average lateral lengths of approximately 8,400 feet, and an average well cost of $4.6 million in 2016. The slight increase in costs is driven by longer lateral wells, which on average are more than 7 percent longer than the previous year.
The company expects to maintain a one-rig drilling program in its Eagle Ford program in 2017 and remains focused on reducing base decline rates, increasing efficiencies and generating high returns in this program. Average well cost in 2017 is expected to be $4.3 million compared with an average well cost of $4.2 million in 2016.
In its Altamont program, the company expects to average two rigs in 2017. The company will also continue its high return recompletion program in 2017. Average well cost in 2017 is expected to be $4.4 million compared with an average well cost of $4.1 million in 2016. The company expects to drill deeper wells in 2017 which contributes to the higher cost.
The table below summarizes the company's operational and financial guidance for 2017 compared with 2016 results, including pro forma 2016 for the Haynesville Shale asset sale completed in May 2016.
2017 |
2016 |
Pro-forma 20164 | ||||
Oil production (MBbls/d) |
45 – 49 |
46.6 |
46.6 | |||
Total production (MBoe/d) |
75 – 82 |
87.6 |
81.4 | |||
Oil & Gas capital ($ million)1,2 |
||||||
Wolfcamp |
$245 – $325 |
$233 |
$233 | |||
Eagle Ford |
$260 – $270 |
$175 |
$175 | |||
Altamont |
$125 – $135 |
$76 |
$76 | |||
Total capital program ($ million) |
$630 – $730 |
$484 |
$484 | |||
Gross well completions |
||||||
Wolfcamp3 |
90 – 105 |
44 |
44 | |||
Eagle Ford |
~60 |
39 |
39 | |||
Altamont |
~25 |
15 |
15 | |||
Total |
175 – 190 |
98 |
98 |
1 Includes 20 - 25 percent non-drill capital | |
2 2016 excludes approximately $1 million of other capital | |
3 Includes completions which are within the DrillCo joint venture with 40 percent of total well costs to EP Energy | |
4 Excludes the impact of the sale of the Haynesville Shale asset which closed on May 3, 2016 |
Webcast Information
EP Energy has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on March 2, to discuss its fourth quarter and full year financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 9258957) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through April 2, 2017 on the company's website in the Investor Center (conference ID# 10101279).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading independent North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in fast-emerging unconventional resource areas. EP Energy is active in all phases of the E&P value chain—exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under these programs adjusted for cash payments made under these plans), transition, restructuring and other costs that affect comparability, gains and losses on extinguishment of debt, gains and/or losses on sale of assets and impairment charges. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net loss to EBITDAX and Adjusted EBITDAX:
Quarter ended December 31, |
Year ended December 31, | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
($ in millions, except equivalent volumes and per unit) | |||||||||||||||
Net loss |
$ |
(140) |
$ |
(3,731) |
$ |
(27) |
$ |
(3,748) |
|||||||
Income tax (benefit) expense |
— |
(565) |
1 |
(578) |
|||||||||||
Interest expense, net of capitalized interest |
81 |
81 |
312 |
330 |
|||||||||||
Depreciation, depletion and amortization |
120 |
246 |
462 |
983 |
|||||||||||
Exploration expense |
2 |
6 |
5 |
18 |
|||||||||||
EBITDAX |
63 |
(3,963) |
753 |
(2,995) |
|||||||||||
Mark-to-market on financial derivatives(1) |
53 |
(209) |
73 |
(667) |
|||||||||||
Cash settlements and cash premiums on financial derivatives(2) |
125 |
293 |
639 |
942 |
|||||||||||
Non-cash portion of compensation expense(3) |
7 |
5 |
19 |
13 |
|||||||||||
Transition, restructuring and other costs(4) |
5 |
— |
15 |
8 |
|||||||||||
Gain on sale of assets |
— |
— |
(78) |
— |
|||||||||||
(Gain) loss on extinguishment of debt |
— |
— |
(384) |
41 |
|||||||||||
Impairment charges |
2 |
4,299 |
2 |
4,299 |
|||||||||||
Adjusted EBITDAX |
$ |
255 |
$ |
425 |
$ |
1,039 |
$ |
1,641 |
|||||||
Total equivalent volumes (MBoe) |
7,594 |
10,362 |
32,077 |
40,033 |
|||||||||||
Adjusted EBITDAX Per Unit (MBoe)(5) |
$ |
33.53 |
$ |
40.94 |
$ |
32.39 |
$ |
40.98 |
____________________ | |
(1) |
Represents the income statement impact of financial derivatives. |
(2) |
Represents actual cash settlements related to financial derivatives. No cash premiums were received or paid for the periods presented. |
(3) |
Cash payments for the quarter and year ended December 31, 2016 were less than $1 million and $3 million, respectively. Cash payments for the quarter and year ended December 31, 2015 were less than $1 million and $8 million, respectively. |
(4) |
Reflects transition and severance costs related to workforce reductions. |
(5) |
Adjusted EBITDAX Per Unit is based on actual amounts rather than the rounded totals presented. |
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the Company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums related to these derivatives), gains and losses on extinguishment of debt, gains and losses on sale of assets, impairment charges, other costs that affect comparability, including transition and restructuring charges and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS: | |||||||||||
Quarter ended December 31, 2016 | |||||||||||
Pre-Tax |
After-Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(140) |
$ |
(0.57) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
178 |
$ |
115 |
$ |
0.47 |
|||||
Transition, restructuring and other costs(4) |
5 |
4 |
0.01 |
||||||||
Impairment charges |
2 |
1 |
— |
||||||||
Valuation allowance on deferred tax assets |
52 |
0.21 |
|||||||||
Total adjustments |
$ |
185 |
$ |
172 |
$ |
0.69 |
|||||
Adjusted EPS |
$ |
0.12 |
|||||||||
Diluted weighted average shares(5) |
247 |
||||||||||
Year ended December 31, 2016 | |||||||||||
Pre-Tax |
After-Tax |
Diluted EPS(1) | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(27) |
$ |
(0.11) |
|||||||
Adjustments(2) |
|||||||||||
Impact of financial derivatives(3) |
$ |
712 |
$ |
457 |
$ |
1.86 |
|||||
Gain on extinguishment of debt |
(384) |
(246) |
(1.00) |
||||||||
Gain on sale of assets |
(79) |
(51) |
(0.21) |
||||||||
Transition, restructuring and other costs(4) |
15 |
10 |
0.04 |
||||||||
Impairment charges |
2 |
1 |
— |
||||||||
Valuation allowance on deferred tax assets |
9 |
$ |
0.04 |
||||||||
Total adjustments |
$ |
266 |
$ |
180 |
$ |
0.73 |
|||||
Adjusted EPS |
$ |
0.62 |
|||||||||
Diluted weighted average shares(5) |
246 |
||||||||||
(1) |
Diluted per share amounts are based on actual amounts rather than the rounded totals presented. |
(2) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(3) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(4) |
Reflects transition and severance costs related to workforce reductions. |
(5) |
Diluted shares include certain restricted stock and performance unit awards. |
Free Cash Flow is defined as net cash provided by operating activities less cash paid for capital expenditures. Below is a reconciliation of our net cash provided by operating activities to Free Cash Flow:
Year ended | |||
2016 | |||
($ in millions) | |||
Net cash provided by operating activities |
$ |
784 |
|
Cash paid for capital expenditures |
533 |
||
Free Cash Flow |
$ |
251 |
|
Net cash used in investing activities |
$ |
(144) |
|
Net cash used in financing activities |
$ |
(646) |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains and/or losses on sales of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under these plans) and transition, restructuring and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to the operation of our assets. We exclude the non-cash portion of compensation expense as well as transition, restructuring and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and these items can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs: | ||||||||||||
Quarter Ended December 31, | ||||||||||||
2016 |
2015 | |||||||||||
Total |
Per Unit |
Total |
Per Unit | |||||||||
Oil and natural gas purchases |
1 |
0.17 |
7 |
0.73 |
||||||||
Transportation costs |
28 |
3.71 |
34 |
3.19 |
||||||||
Lease operating expense |
42 |
5.59 |
47 |
4.53 |
||||||||
General and administrative |
45 |
5.85 |
34 |
3.30 |
||||||||
Depreciation, depletion and amortization |
120 |
15.78 |
246 |
23.73 |
||||||||
Impairment charges |
2 |
0.21 |
4,299 |
414.84 |
||||||||
Exploration and other expense |
2 |
0.23 |
6 |
0.57 |
||||||||
Taxes, other than income taxes |
7 |
1.08 |
15 |
1.50 |
||||||||
Total operating expenses |
247 |
32.62 |
4,688 |
452.39 |
||||||||
Adjustments: |
||||||||||||
Depreciation, depletion and amortization |
(120) |
(15.78) |
(246) |
(23.73) |
||||||||
Impairment charges |
(2) |
(0.21) |
(4,299) |
(414.84) |
||||||||
Exploration expense |
(2) |
(0.23) |
(6) |
(0.53) |
||||||||
Non-cash portion of compensation expense |
(7) |
(0.89) |
(5) |
(0.50) |
||||||||
Transition, restructuring and other costs |
(5) |
(0.71) |
— |
— |
||||||||
Adjusted cash operating costs and per unit adjusted cash costs |
111 |
14.80 |
132 |
12.79 |
||||||||
Total consolidated equivalent volumes (MBoe) |
7,594 |
10,362 |
||||||||||
Year Ended December 31, | ||||||||||||
2016 |
2015 | |||||||||||
Total |
Per-Unit |
Total |
Per-Unit | |||||||||
Oil and natural gas purchases |
10 |
0.32 |
31 |
0.79 |
||||||||
Transportation costs |
109 |
3.41 |
116 |
2.88 |
||||||||
Lease operating expense |
159 |
4.97 |
186 |
4.64 |
||||||||
General and administrative |
146 |
4.54 |
148 |
3.71 |
||||||||
Depreciation, depletion and amortization |
462 |
14.40 |
983 |
24.54 |
||||||||
Gain on sale of assets |
(78) |
(2.44) |
— |
— |
||||||||
Impairment charges |
2 |
0.05 |
4,299 |
107.38 |
||||||||
Exploration and other expense |
5 |
0.16 |
20 |
0.50 |
||||||||
Taxes, other than income taxes |
50 |
1.58 |
80 |
2.00 |
||||||||
Total operating expenses |
865 |
26.99 |
5,863 |
146.44 |
||||||||
Adjustments: |
||||||||||||
Depreciation, depletion and amortization |
(462) |
(14.40) |
(983) |
(24.54) |
||||||||
Impairment charges |
(2) |
(0.05) |
(4,299) |
(107.38) |
||||||||
Gain on sale of assets |
78 |
2.44 |
— |
— |
||||||||
Exploration expense |
(5) |
(0.16) |
(18) |
(0.44) |
||||||||
Non-cash portion of compensation expense |
(19) |
(0.58) |
(13) |
(0.32) |
||||||||
Transition, restructuring and other costs |
(15) |
(0.47) |
(8) |
(0.20) |
||||||||
Adjusted cash operating costs and per-unit adjusted cash costs |
440 |
13.77 |
542 |
13.56 |
||||||||
Total consolidated equivalent volumes (MBoe) |
32,077 |
40,033 |
||||||||||
(1) |
Per unit costs are based on actual amounts rather than the rounded totals presented. |
EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EPS is used by management and we believe is a valuable measure of operating performance. Free Cash Flow is used by management and we believe provides investors with useful information for analysis of the company's ability to internally fund capital expenditures and to service or incur additional debt. Adjusted Cash Operating Costs is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Adjusted EPS should not be used as an alternative to earnings (loss) per share or other measure of financial performance presented in accordance with GAAP. EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit should not be used as an alternative to net income (loss), operating income (loss), operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Free Cash Flow should not be used as an alternative to operating or investing cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. Adjusted Cash Operating Costs should not be used as an alternative to operating expenses, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. For example, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and sustained low oil, natural gas, and NGL prices; the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; changes in commodity prices and basis differentials for oil and natural gas; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors, suppliers and third party operators; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
SOURCE EP Energy Corporation
HOUSTON, Feb. 22, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Thursday, March 2, to discuss its fourth quarter and full year 2016 financial and operational results. The company's fourth quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, March 1, 2017.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 9258957) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through April 1, 2017 on the company's website in the Investor Center (conference ID# 10101279). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading independent North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
SOURCE EP Energy Corporation
HOUSTON, Feb. 9, 2017 /PRNewswire/ -- Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation (NYSE: EPE), will present Tuesday, February 14, at the Credit Suisse 22nd Annual Energy Summit in Vail, Colorado. The presentation will begin at 10:55 a.m. MST, 11:55 a.m. CST with an audio webcast available on the Investor Center page of EP Energy's website at epenergy.com.
Presentation slides will be available prior to the presentation on the Investor Center page of the company's website.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
SOURCE EP Energy Corporation
HOUSTON, Feb. 1, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), today announced the pricing of the previously announced unregistered offering of 8.00% Senior Secured Notes due 2025 (the "Notes") at an issue price of 100%. The size of the offering was also increased from $600.0 million to $1,000.0 million. The offering is expected to close on February 6, 2017, subject to certain closing conditions. The Issuers intend to use the proceeds from the offering of the Notes, together with available cash on hand, to (i) repay in full EP Energy's senior secured term loans due 2021, repurchase up to $250 million aggregate principal amount of the Issuers' 9.375% Senior Notes due 2020 in the open market, repay amounts outstanding under EP Energy's senior reserve-based revolving credit facility and for general corporate purposes and (ii) pay related fees and expenses.
Additional Information
The Notes are being offered in a private offering that is exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), only to qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non‐U.S. investors pursuant to Regulation S. The Notes have not been registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from registration requirements or a transaction not subject to the registration requirements of the Securities Act or any state securities laws.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, EP Energy's ability to complete the offering of the Notes, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; EP Energy's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; EP Energy's ability to comply with the covenants in various financing documents; EP Energy's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by EP Energy, or where operations of EP Energy are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in EP Energy's Securities and Exchange Commission filings. While EP Energy makes these statements and projections in good faith, neither EP Energy nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
SOURCE EP Energy Corporation
HOUSTON, Jan. 31, 2017 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), intend to offer $600.0 million aggregate principal amount of its Senior Secured Notes due 2025 (the "Notes") in a private placement.
The Issuers intend to use the proceeds from the offering of the Notes, together with available cash on hand, to (i) repay in full EP Energy's senior secured term loans due 2021 and (ii) pay related fees and expenses.
Additional Information
The Notes are being offered in a private offering that is exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), only to qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non-U.S. investors pursuant to Regulation S. The Notes have not been registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from registration requirements or a transaction not subject to the registration requirements of the Securities Act or any state securities laws.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, EP Energy's ability to complete the offering of the Notes, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; EP Energy's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; EP Energy's ability to comply with the covenants in various financing documents; EP Energy's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by EP Energy, or where operations of EP Energy are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in EP Energy's Securities and Exchange Commission filings. While EP Energy makes these statements and projections in good faith, neither EP Energy nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
SOURCE EP Energy Corporation
HOUSTON, Jan. 26, 2017 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today announced it has, through a subsidiary, entered into a drilling joint venture with private capital investor, Wolfcamp Drillco Operating L.P. (Investor), to fund future oil and natural gas development in its Wolfcamp program.
Drilling Joint Venture highlights
"We are pleased to announce our Permian drilling joint venture, which will enable us to accelerate the development of our largest strategic asset in a balance sheet friendly manner," said Brent Smolik, chairman, president, and chief executive officer of EP Energy Corporation. "During the past year, we significantly increased the value of our Wolfcamp asset with improved well performance, a lower cost structure and reduced royalty rates. This new capital commitment further improves and illuminates the acreage value of our Wolfcamp program."
The Investor is participating in the development of an up to 150 well program in two separate 75 well tranches in areas of the company's acreage, including Reagan and Crockett Counties.
The Investor will fund 60 percent of the drilling, completion and equipping costs in exchange for a 50 percent working interest in the joint venture wells. Once the Investor achieves a 12 percent internal rate of return on its invested capital in each tranche, its working interest will revert to 15 percent. EP Energy will retain operational control of the joint venture assets. The first wells under the joint venture began production in January 2017.
Wolfcamp Drillco Operating L.P. is managed by, and its equity is owned by, affiliates of Apollo Global Management LLC, affiliates, of which beneficially own approximately 45 percent of EP Energy's common stock and have representatives on its board of directors. The transaction was approved by the disinterested members of the EP Energy's board of directors.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward‐looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the supply and demand for oil, natural gas and NGLs; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; changes in commodity prices and basis differentials for oil and natural gas; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; political and currency risks associated with international operations of the company; competition; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward‐looking statements made herein or any other forward‐looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
SOURCE EP Energy Corporation
HOUSTON, Nov. 17, 2016 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), today announced the pricing of the previously announced unregistered offering of $500.0 million aggregate principal amount of 8.00% Senior Secured Notes due 2024 (the "Notes") at an issue price of 100%. The size of the offering was increased from $350.0 million to $500.0 million and the maturity of the notes was extended from 2023 to 2024. The offering is expected to close on November 29, 2016, subject to certain closing conditions.
The Issuers intend to use the proceeds from the offering of the Notes (i) to repay amounts outstanding under their senior reserve-based revolving credit facility and/or for other general corporate purposes and (ii) to pay related fees and expenses.
Additional Information
The Notes are being offered in a private offering that is exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), only to qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non‐U.S. investors pursuant to Regulation S. The Notes have not been registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from registration requirements or a transaction not subject to the registration requirements of the Securities Act or any state securities laws.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, EP Energy's ability to complete the offering of the Notes, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; EP Energy's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; EP Energy's ability to comply with the covenants in various financing documents; EP Energy's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by EP Energy, or where operations of EP Energy are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in EP Energy's Securities and Exchange Commission filings. While EP Energy makes these statements and projections in good faith, neither EP Energy nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy LLC
HOUSTON, Nov. 16, 2016 /PRNewswire/ -- EP Energy LLC ("EP Energy"), a wholly-owned subsidiary of EP Energy Corporation (NYSE: EPE), today announced that it and its wholly-owned subsidiary, Everest Acquisition Finance Inc., as co-issuer (together with EP Energy, the "Issuers"), intend to offer $350.0 million aggregate principal amount of its Senior Secured Notes due 2023 (the "Notes") in a private placement.
The Issuers intend to use the proceeds from the offering of the Notes (i) to repay amounts outstanding under their senior reserve-based revolving credit facility and/or for other general corporate purposes and (ii) to pay related fees and expenses.
Additional Information
The Notes are being offered in a private offering that is exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), only to qualified institutional buyers in reliance on Rule 144A under the Securities Act, and outside the United States, only to non‐U.S. investors pursuant to Regulation S. The Notes have not been registered under the Securities Act or any state securities laws and may not be offered or sold in the United States absent an effective registration statement or an applicable exemption from registration requirements or a transaction not subject to the registration requirements of the Securities Act or any state securities laws.
This press release shall not constitute an offer to sell or the solicitation of an offer to buy any security and shall not constitute an offer, solicitation or sale in any jurisdiction in which such offering, solicitation or sale would be unlawful.
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, EP Energy's ability to complete the offering of the Notes, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; EP Energy's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; EP Energy's ability to comply with the covenants in various financing documents; EP Energy's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by EP Energy, or where operations of EP Energy are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in EP Energy's Securities and Exchange Commission filings. While EP Energy makes these statements and projections in good faith, neither EP Energy nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
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SOURCE EP Energy Corporation
HOUSTON, Oct. 26, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported third quarter 2016 financial and operational results.
Third quarter 2016 Highlights
Financial improvements
"We are pleased with another quarter of strong operational performance which stabilized oil production volumes," said Brent Smolik, chairman, president, and chief executive officer of EP Energy Corporation. "During the quarter, we continued to add value with improved well performance, increased capital efficiency, and lower costs. We have also significantly reduced debt in the past year. We continue to evaluate options to further improve the value of our company in any commodity price environment."
EP Energy reported an $0.18 diluted net loss per share and a $0.10 adjusted earnings per share (EPS) for the third quarter of 2016. Reported net loss was $43 million for the third quarter of 2016, down from $176 million net income in the same 2015 period. Adjusted EBITDAX for the third quarter of 2016 was $250 million, down from $446 million in the third quarter of 2015, due primarily to lower oil and natural gas production volumes and lower realized pricing, partially offset by lower operating costs.
Operating expenses for the third quarter of 2016 were $249 million, down from $398 million in the third quarter of 2015. Adjusted cash operating costs were $107 million for the third quarter 2016, down from $131 million in the same 2015 period. The company noted that this metric now includes costs for transportation and commodity purchases. The improvement in 2016 is primarily due to lower lease operating costs (LOE), production taxes, transportation, and general and administrative costs. For the third quarter 2016, adjusted cash operating costs were $14.50 per barrel of oil equivalent (Boe), up from $12.49 per Boe for the third quarter of 2015, due primarily to lower production volumes.
Total capital expenditures in the third quarter of 2016 were $146 million, with over half invested in the company's Wolfcamp program. The company's overall activity levels in 2016 were significantly reduced compared to 2015. In the third quarter 2016, the company completed 30 wells compared to 49 wells in the third quarter of 2015. Average daily oil production was 45.0 MBbls/d, down 28 percent from 62.1 MBbls/d in the third quarter of 2015. Total equivalent production was 79.6 thousand barrels of oil equivalent per day (MBoe/d), down from 114.5 MBoe/d in the same period last year. The reduction in equivalent volumes included an 85 million cubic feet per day (14.3 MBoe/d) reduction attributed to the sale of the company's Haynesville Shale asset which closed on May 3, 2016.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
During the third quarter, EP Energy accomplished several milestones which improved the company's financial position.
The company continued to make additional debt repurchases during the quarter and year-to-date debt reductions were over $1 billion through September 30, 2016. In addition, EP Energy also successfully exchanged nearly all of its term loans and extended the maturity of the new loans to 2021, which eliminated the potential springing maturity of the RBL Facility in 2017. The company's RBL facility matures in May 2019. The company is in the process of completing its semi-annual RBL Facility borrowing base redetermination and expects to maintain its borrowing base at the current level of $1.65 billion.
The company continues to prioritize balance sheet improvements and the extension of its liquidity position.
Cash flows from operations were $658 million and cash capital expenditures were $398 million year-to-date September 30, 2016. In the third quarter of 2016, EP Energy had $112 million of positive free cash flow and $260 million year-to-date, continuing the trend of positive free cash flow that began in the second half of 2015.
During the third quarter of 2016, EP Energy established a 2017 natural gas hedge position and now has approximately 23.7 trillion British thermal units (TBtu) of natural gas swapped at $3.25 per million British thermal units (MMBtu) for 2017.
As of September 30, 2016, EP Energy had liquidity of approximately $803 million with total debt of $3.9 billion and net debt of $3.8 billion.
Eagle Ford Program
In the third quarter of 2016, EP Energy completed 10 wells in its Eagle Ford program compared to 24 wells in the third quarter of 2015. The company produced 24.0 MBbls/d of oil, a 40 percent decrease compared with the third quarter of 2015. The oil production decline was due to significantly lower activity levels in 2016. Total equivalent production for the third quarter of 2016 was 40.6 MBoe/d.
The company was able to reduce production decline rates in the quarter through base optimization activities. EP Energy currently has one drilling rig active in the Eagle Ford which was added in October. The company is focused on continuing to improve well performance, while reducing well costs and LOE.
Wolfcamp Program
In the third quarter of 2016, the company completed 13 wells in its Wolfcamp program and produced 9.3 MBbls/d of oil, essentially flat to the same period in 2015 despite lower activity levels. Total equivalent production for the third quarter of 2016 was 22.1 MBoe/d. Results from the company's 2016 wells are continuing to outperform its 600 MBoe type curve.
EP Energy currently has one drilling rig active in the Wolfcamp and significantly increased activities with more well completions in the third quarter than in the first half of 2016. The company expects continued focus on the Wolfcamp asset, as well economics continue to improve due to stronger well performance, decreasing capital and operating costs, and the added benefit of the sliding scale royalty development agreement.
Altamont Program
In the third quarter of 2016, EP Energy completed 7 wells in its Altamont program, in line with the third quarter of 2015. The company produced 11.7 MBbls/d of oil, an 8 percent decrease compared with the same period in 2015. Oil production declined primarily due to lower activity levels in 2016, partially offset by the company's success with its recompletion program. Altamont total equivalent production for the third quarter of 2016 was 16.8 MBoe/d.
EP Energy has one partnership drilling rig active in the Altamont and continues to benefit from outstanding results in its recompletion program.
In the third quarter of 2016, realized pricing for Altamont production volumes continued to improve relative to WTI as a result of improved contract terms and local market conditions as compared to the same period in 2015.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program, which provides substantial 2016 and 2017 commodity price protection. Year-to-date 2016, the company has realized $514 million of settlements on its financial derivatives, which included $145 million in the third quarter 2016.
A summary of the company's open hedge positions is listed below, which includes the recent addition of 2017 natural gas hedges:
2016 |
2017 |
||||||||
Total Fixed Price Hedges |
|||||||||
Oil volumes (MMBbls)(1) |
3.9 |
12.8 |
|||||||
Average floor price ($/Bbl) |
$ |
80.77 |
$ |
62.34 |
|||||
Natural gas volumes (TBtu) |
6.4 |
23.7 |
|||||||
Average floor price ($/MMBtu) |
$ |
3.34 |
$ |
3.25 |
Note: Positions are as of October 24, 2016 (Contract months: October 2016 - Forward). |
(1) 2017 positions include WTI three way collars of 8.8 MMBbls. |
At September 30, 2016, the mark-to-market value of the company's hedge contracts was $236 million.
Updated 2016 Outlook
EP Energy updated its 2016 outlook which reflects three quarters of actual results and increased capital efficiency due to well cost reductions and better well performance. The company updated its capital spending estimate as a result of increased capital efficiency.
The company's outlook includes more well completions in the second half of 2016 compared to the first half of the year. The higher completion count and better well performance resulted in third quarter 2016 oil production which was essentially flat with the second quarter of 2016. The company expects to continue this trend in the fourth quarter 2016 and as a result has increased its guidance ranges for oil and total production.
The updated outlook is shown below:
Guidance |
Updated Guidance | |||
Capital program ($ million) |
$475 - $505 |
~$495 | ||
Production |
||||
Total production (MBoe/d) |
83 - 86 |
85.5 - 87.5 | ||
Oil production (MBbls/d) |
45 - 47 |
46 - 47 | ||
Well completions |
85 - 95 |
~95 |
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on October 27, 2016, to discuss its third quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 9459098) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through Friday, November 25, 2016 on the company's website in the Investor Center (conference ID# 10093763).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums paid or received related to these derivatives), gains and losses on extinguishment of debt, gains and losses on sales of assets, other costs that affect comparability, including transition and restructuring charges and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net loss per share to Adjusted EPS:
Quarter ended September 30, 2016 | |||||||||||
Pre Tax |
After Tax |
Diluted | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net loss |
$ |
(43) |
$ |
(0.18) |
|||||||
Adjustments(1) |
|||||||||||
Impact of financial derivatives(2) |
$ |
102 |
$ |
65 |
$ |
0.27 |
|||||
Gain on extinguishment of debt |
(26) |
(16) |
(0.07) |
||||||||
Loss on sale of assets |
4 |
2 |
0.01 |
||||||||
Valuation allowance on deferred tax assets |
16 |
0.07 |
|||||||||
Total adjustments |
$ |
80 |
$ |
67 |
$ |
0.28 |
|||||
Adjusted EPS |
$ |
0.10 |
|||||||||
Diluted weighted average shares(3) |
245 |
(1) All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(2) Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. |
(3) Diluted shares include certain restricted stock and performance unit awards. |
Free Cash Flow is defined as net cash provided by operating activities less cash paid for capital expenditures. Below is a reconciliation of our Free Cash Flow to our net cash provided by operating activities:
Nine |
Six months |
Quarter | |||||||||
2016 | |||||||||||
($ in millions) | |||||||||||
Net cash provided by operating activities |
$ |
658 |
$ |
406 |
$ |
252 |
|||||
Cash paid for capital expenditures |
(398) |
(258) |
(140) |
||||||||
Free Cash Flow |
$ |
260 |
$ |
148 |
$ |
112 |
|||||
Net cash (used in) provided by investing activities |
$ |
(9) |
$ |
132 |
$ |
(141) |
|||||
Net cash used in financing activities |
$ |
(635) |
$ |
(525) |
$ |
(110) |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums paid or received related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans), transition, restructuring and other costs, gains and losses on extinguishment of debt, and gains and losses on sales of assets. Adjusted EBITDAX Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net (loss) income to EBITDAX and Adjusted EBITDAX:
Quarter ended September 30, | |||||||
2016 |
2015 | ||||||
($ in millions, except equivalent volumes | |||||||
Net (loss) income |
$ |
(43) |
$ |
176 |
|||
Income tax expense |
1 |
95 |
|||||
Interest expense, net of capitalized interest |
74 |
84 |
|||||
Depreciation, depletion and amortization |
132 |
260 |
|||||
Exploration expense |
1 |
2 |
|||||
EBITDAX |
165 |
617 |
|||||
Mark-to-market on financial derivatives(1) |
(43) |
(434) |
|||||
Cash settlements and cash premiums on financial derivatives(2) |
145 |
258 |
|||||
Non-cash portion of compensation expense(3) |
5 |
5 |
|||||
Loss on sale of assets |
4 |
— |
|||||
Gain on extinguishment of debt |
(26) |
— |
|||||
Adjusted EBITDAX |
$ |
250 |
$ |
446 |
|||
Total equivalent volumes (MBoe) |
7,326 |
10,533 |
|||||
Adjusted EBITDAX Per Unit (MBoe)(4) |
$ |
34.18 |
$ |
42.38 |
(1) Represents the income statement impact of financial derivatives. |
(2) Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(3) Cash payments for both the quarters ended September 30, 2016 and 2015 were less than $1 million. |
(4) Adjusted EBITDAX Per Unit is based on actual total amounts rather than the rounded totals presented. |
Adjusted cash operating costs is a non-GAAP measure that is defined as total operating expenses, excluding depreciation, depletion and amortization expense, exploration expense, impairment charges, gains and/or losses on sales of assets, the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans) and transition, restructuring and other costs that affect comparability. We use this measure to describe the costs required to directly or indirectly operate our existing assets and produce and sell our oil and natural gas, including the costs associated with the delivery and purchases and sales of produced commodities. Accordingly, we exclude depreciation, depletion, and amortization and impairment charges as such costs are non-cash in nature. We exclude exploration expense from our measure as it is substantially non-cash in nature and is not related to the costs to operate our existing assets. Similarly, gains and losses on the sale of assets are excluded as they are unrelated to the operation of our assets. We exclude the non-cash portion of compensation expense as well as transition, restructuring and other costs that affect comparability, as we believe such adjustments allow investors to evaluate our costs against others in our industry and these items can vary across companies due to different ownership structures, compensation objectives or the occurrence of transactions.
Below is a reconciliation of our GAAP operating expenses to non-GAAP adjusted cash operating costs:
Quarter ended September 30, | ||||||||||||||||
2016 |
2015 | |||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Oil and natural gas purchases |
$ |
2 |
$ |
0.25 |
$ |
9 |
$ |
0.90 |
||||||||
Transportation costs |
27 |
3.71 |
30 |
2.87 |
||||||||||||
Lease operating expense |
37 |
5.13 |
45 |
4.25 |
||||||||||||
General and administrative |
31 |
4.21 |
32 |
3.02 |
||||||||||||
Depreciation, depletion and amortization |
132 |
17.97 |
260 |
24.69 |
||||||||||||
Loss on sale of assets |
4 |
0.53 |
— |
— |
||||||||||||
Exploration and other expense |
1 |
0.21 |
2 |
0.16 |
||||||||||||
Taxes, other than income taxes |
15 |
1.94 |
20 |
1.89 |
||||||||||||
Total operating expenses |
$ |
249 |
$ |
33.95 |
$ |
398 |
$ |
37.78 |
||||||||
Adjustments: |
||||||||||||||||
Depreciation, depletion and amortization |
$ |
(132) |
$ |
(17.97) |
$ |
(260) |
$ |
(24.69) |
||||||||
Loss on sale of assets |
(4) |
(0.53) |
— |
— |
||||||||||||
Exploration expense |
(1) |
(0.21) |
(2) |
(0.16) |
||||||||||||
Transition/restructuring costs, non-cash portion of compensation expense and other(2) |
(5) |
(0.74) |
(5) |
(0.44) |
||||||||||||
Adjusted cash operating costs and per-unit adjusted cash operating costs |
$ |
107 |
$ |
14.50 |
$ |
131 |
$ |
12.49 |
||||||||
Total consolidated equivalent volumes (MBoe) |
7,326 |
10,533 |
(1) Per unit costs are based on actual total amounts rather than the rounded totals presented. |
(2) For both the quarters ended September 30, 2016 and 2015, amount includes approximately $5 million of non-cash compensation expense. |
Net debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents. At December 31, 2015, the company's net debt was approximately $4.8 billion (total debt of approximately $4,869 million less cash and cash equivalents of approximately $26 million). At September 30, 2016, the company's net debt was approximately $3.8 billion (total debt of approximately $3,856 million less cash and cash equivalents of approximately $40 million).
Adjusted EPS, EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Per Unit are used by management and we believe provide investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. Free Cash Flow is used by management and we believe provides investors with useful information for analysis of the company's ability to internally fund capital expenditures and to service or incur additional debt. Adjusted Cash Operating Costs per unit is used by management as a performance measure, and we believe provides investors valuable information related to our operating performance and our operating efficiency relative to other industry participants and comparatively over time across our historical results. We believe Net Debt provides useful information to investors for analysis of the Company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow, Adjusted Cash Operating Costs and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP or as an alternative to net income (loss), operating income (loss), earnings (loss) per share, operating or investing cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. For example, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow, Adjusted Cash Operating Costs and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Per Unit, Free Cash Flow and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
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SOURCE EP Energy Corporation
HOUSTON, Oct. 21, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Thursday, October 27, to discuss its third quarter 2016 financial and operational results. The company's third quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, October 26, 2016.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 9459098) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through Friday, November 25, 2016 on the company's website in the Investor Center or by dialing 877-344-7529 (conference ID# 10093763). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy Corporation
HOUSTON, Sept. 2, 2016 /PRNewswire/ -- Brent Smolik, chairman, president and chief executive officer of EP Energy Corporation (NYSE: EPE), is scheduled to present Thursday, September 8, at the Barclays Capital CEO Energy-Power Conference in New York City. The presentation will begin at 8:25 a.m. EDT, 7:25 a.m. CDT.
A live webcast of the presentation, and accompanying slides, will be made available through EP Energy's website at epenergy.com. A replay of the webcast will be available through October 30, 2016.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy Corporation
HOUSTON, Aug. 3, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported second quarter 2016 financial and operational results.
Second quarter 2016 results
Continued financial improvement
"We had another solid quarter of operational and financial performance and achieved several significant milestones," said Brent Smolik, chairman, president, and chief executive officer of EP Energy Corporation. "The value of our Wolfcamp asset has meaningfully improved over the last six to 12 months due to increased technical knowledge, lower costs, improved well performance and enhanced well-level returns. We continue to benefit from a low-cost structure and reduced capital cost and lease operating expenses (LOE) across the company. We've strengthened our financial position and have reduced debt by $900 million since the beginning of the year."
EP Energy reported $0.25 diluted earnings per share and $0.21 Adjusted EPS for the second quarter of 2016. Reported net income was $62 million, up from a $212 million net loss in the second quarter of 2015. Adjusted EBITDAX for the second quarter of 2016 was $256 million, down from $404 million in the second quarter of 2015, due primarily to lower oil production volumes and lower realized pricing, partially offset by lower operating costs. Operating expenses for the second quarter of 2016 were $127 million, which includes a gain on the sale of assets of $82 million, down from $397 million in the second quarter of 2015. Total adjusted cash operating costs for the quarter ended June 30, 2016 were $10.28 per barrel of oil equivalent (Boe), an improvement from $10.74 per Boe for the second quarter of 2015, due primarily to lower general and administrative costs, lower production taxes, and lower lease operating costs, partially offset by lower production.
During the quarter, the company's activity levels were significantly reduced compared to the same period in 2015. Total capital expenditures in the second quarter of 2016 were $94 million, with nearly half invested in the company's Wolfcamp program. During the second quarter of 2016, the company completed 15 wells. As a result, average daily oil production decreased 29 percent to 45.1 MBbls/d, down from 63.4 MBbls/d in the second quarter of 2015. Total equivalent production was 84.5 thousand barrels of oil equivalent per day (MBoe/d), down from 109.0 MBoe/d in the same period last year. The reduction in equivalent volumes included a 33 million cubic feet per day (5.5 MBoe/d) reduction attributed to the sale of the company's Haynesville Shale asset which closed on May 3, 2016.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
During the second quarter, EP Energy accomplished several milestones which improved the company's financial position.
As previously announced in May, the company completed its semi-annual borrowing base redetermination, divested its Haynesville natural gas assets and executed open-market debt repurchases of $609 million of face value.
Since that time, the company has made additional debt repurchases of $182 million of face value for approximately $106 million in cash. Year-to-date the company has repurchased $791 million of face value debt for $394 million in cash, through August 3, 2016. The company now expects its 2016 debt repurchases and retirements will reduce annualized interest expense by an estimated $62 million.
In the second quarter of 2016, EP Energy had $26 million of positive free cash flow and year-to-date June 30, 2016 free cash flow of $148 million, continuing the trend of positive free cash flow that began in the second half of 2015. Year-to-date, cash flows from operations were $406 million and cash capital expenditures were $258 million. The company expects to generate approximately $250 million of positive free cash flow for the full-year 2016.
During the second quarter, EP Energy significantly increased its 2017 oil hedge position and now has a weighted average price floor of $62.34 per barrel on approximately 12.8 million barrels of oil (MMBbls) for 2017. The company also added to its 2016 natural gas hedges and now has approximately 11.3 trillion British thermal units (TBtu) swapped at $3.39 per million British thermal units (MMBtu).
As of June 30, 2016, EP Energy had liquidity of approximately $750 million and net debt of $3.9 billion.
Eagle Ford Program
In the second quarter of 2016, EP Energy completed 8 wells in its Eagle Ford program compared to 42 wells in the second quarter of 2015. The company produced 27.3 MBbls/d of oil, a 34 percent decrease compared with the second quarter of 2015. The oil production decline was primarily due to significantly lower activity levels. Total equivalent production for the second quarter of 2016 was 45.0 MBoe/d.
EP Energy had one drilling rig running during the quarter and remains focused on further well cost and LOE reduction.
Wolfcamp Program
In the second quarter of 2016, the company completed 5 wells in late June in its Wolfcamp program and produced 6.8 MBbls/d of oil, down 24 percent from the same period in 2015. Oil production declined primarily due to lower activity levels. Total equivalent production for the second quarter of 2016 was 17.6 MBoe/d. Results from the company's 2016 wells are outperforming the company's 600 MBoe type curve.
During the quarter, EP Energy significantly increased the long-term value of its Wolfcamp asset. The company further refined its drilling and completion design and is generating well results above expectations. Well costs and LOE have also continued to improve.
The company also amended its development agreement with the University Lands providing flexibility to extend the leasehold time frame nearly four years to the end of 2021 with an increase in annual well completion requirements from six wells per year to 34, 55 and 55 wells in 2016, 2017 and 2018, respectively. In addition, the amendment includes a sliding scale royalty framework that improves well returns in the current price environment. The royalty rates associated with the sliding scale framework are 12.5 percent at $50 WTI and below, 18.75 percent at $60 WTI and below, 25 percent at $80 WTI and below, and 28 percent above $80 WTI.
The company has resumed drilling as a result of enhanced returns, adding a rig in May, and will shift more of its 2016 capital to this rapidly improving program.
Altamont Program
In the second quarter of 2016, EP Energy completed 2 wells in its Altamont program compared to 12 wells in the second quarter of 2015. The company produced 11.0 MBbls/d of oil, a 15 percent decrease compared with the same period in 2015. Oil production declined primarily due to lower activity levels, partially offset by the company's success with its recompletion program. Altamont total equivalent production for the second quarter of 2016 was 15.5 MBoe/d.
The company had one partnership drilling rig running during the second quarter. Also in the quarter, EP Energy increased its recompletion program which is generating encouraging results.
In the second quarter of 2016, realized pricing in the program continued to improve relative to WTI as a result of improved contract terms and local market conditions as compared to the same period in 2015.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program, which provides substantial 2016 and 2017 commodity price protection. In the second quarter of 2016, the company realized $157 million of settlements on its financial derivatives.
A summary of the company's open hedge positions is listed below:
2016 |
2017 |
||||||||
Total Fixed Price Hedges |
|||||||||
Oil volumes (MMBbls)(1) |
7.8 |
12.8 |
|||||||
Average floor price ($/Bbl) |
$ |
80.67 |
$ |
62.34 |
|||||
Natural gas volumes (TBtu) |
11.3 |
— |
|||||||
Average floor price ($/MMBtu) |
$ |
3.39 |
$ |
— |
Note: Positions are as of June 30, 2016 (Contract months: July 2016 - Forward). |
(1) 2017 positions include WTI three way collars of 8.8 MMBbls. |
During the quarter, the company entered into additional 2017 oil hedge positions and 2016 natural gas hedge positions. For 2016, the company added 7.7 TBtu of natural gas fixed price swaps. EP Energy also added 8.8 MMBbls of three way collar oil contracts for 2017 with an average floor price of $61 per barrel. The company also has 0.4 MMBbls of remaining offsetting contracts that locked in a portion of its hedge gains for the year.
At June 30, 2016, the mark-to-market value of the company's hedge contracts was approximately $340 million including the value of the offsetting contracts.
Updated 2016 Outlook
EP Energy updated its 2016 outlook which reflects two quarters of actual results and increased capital efficiency due to well cost reductions and better well performance. With the recent decline in oil prices, the company expects to maintain capital spending at the low end of previous guidance and generate free cash flow for the balance of the year while remaining well positioned for a future price recovery.
The company's outlook includes more well completions in the second half of 2016 compared to the first half of the year. The higher completion count and increased well performance is expected to stabilize production volumes in the second half of 2016. The updated outlook, which includes narrower ranges for capital and production volumes, is shown below:
Guidance |
Updated Guidance | |||
Capital program ($ million) |
$500 - $900 |
$475 - $505 | ||
Production |
||||
Total production (MBoe/d) |
81 - 88 |
83 - 86 | ||
Oil production (MBbls/d) |
45 - 50 |
45 - 47 | ||
Well completions |
75 - 160 |
85 - 95 | ||
Adjusted cash operating costs (per Boe) |
$10.40 - $11.40 |
$10.45 - $10.85 | ||
Transportation cost (per Boe) |
$3.30 - $3.40 |
$3.55 - $3.70 | ||
DD&A (per Boe) |
$13.00 - $14.00 |
$13.00 - $14.00 |
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 10:00 a.m. Eastern Time, 9:00 a.m. Central Time, on August 4, 2016, to discuss its second quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 3596277) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through Friday, September 2, 2016 on the company's website in the Investor Center (conference ID# 10089555).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in key phases of the E&P value chain—acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is calculated as net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums paid or received related to these derivatives), gains and losses on extinguishment of debt, gains and losses on sales of assets, other costs that affect comparability, including transition and restructuring charges and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of consolidated diluted net income per share to Adjusted EPS:
Quarter ended June 30, 2016 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net income |
$ |
62 |
$ |
0.25 |
|||||||
Adjustments(1) |
|||||||||||
Impact of financial derivatives(2) |
$ |
262 |
$ |
168 |
$ |
0.69 |
|||||
Transition, restructuring and other costs(3) |
2 |
1 |
0.01 |
||||||||
Gain on extinguishment of debt |
(162) |
(104) |
(0.42) |
||||||||
Gain on sale of assets |
(83) |
(53) |
(0.22) |
||||||||
Valuation allowance on deferred tax assets |
(24) |
(0.10) |
|||||||||
Total adjustments |
$ |
19 |
$ |
(12) |
$ |
(0.04) |
|||||
Adjusted EPS |
$ |
0.21 |
|||||||||
Diluted weighted average shares(4) |
245 |
(1) |
All individual adjustments for the period presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(2) |
Represents mark-to-market impact net of cash settlements and cash premiums related to financial derivatives. |
(3) |
Reflects transition and severance costs related to workforce reductions. |
(4) |
Fully diluted shares consist of certain restricted stock and performance unit awards. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of cash settlements and cash premiums paid or received related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans), transition, restructuring and other costs, gains and losses on extinguishment of debt, and gains and losses on sales of assets. Adjusted EBITDAX Margin Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our consolidated net income (loss) to EBITDAX and Adjusted EBITDAX:
Quarter ended | |||||||
2016 |
2015 | ||||||
($ in millions, except equivalent volumes | |||||||
Net income (loss) |
$ |
62 |
$ |
(212) |
|||
Income tax benefit |
— |
(118) |
|||||
Interest expense, net of capitalized interest |
73 |
81 |
|||||
Depreciation, depletion and amortization |
97 |
253 |
|||||
Exploration expense |
1 |
5 |
|||||
EBITDAX |
233 |
9 |
|||||
Mark-to-market on financial derivatives(1) |
105 |
179 |
|||||
Cash settlements and cash premiums on financial derivatives(2) |
157 |
177 |
|||||
Non-cash portion of compensation expense(3) |
3 |
(2) |
|||||
Transition, restructuring and other costs(4) |
2 |
— |
|||||
Gain on sale of assets |
(82) |
— |
|||||
(Gain) loss on extinguishment of debt |
(162) |
41 |
|||||
Adjusted EBITDAX |
$ |
256 |
$ |
404 |
|||
Total equivalent volumes (MBoe) |
7,691 |
9,920 |
|||||
Adjusted EBITDAX Margin Per Unit (MBoe)(5) |
$ |
33.27 |
$ |
40.75 |
(1) |
Represents the income statement impact of financial derivatives. |
(2) |
Represents actual cash settlements related to financial derivatives. There were no cash premiums received or paid for the periods presented. |
(3) |
Cash payments for the quarters ended June 30, 2016 and 2015 were $3 million and $7 million, respectively. |
(4) |
Reflects transition and severance costs related to workforce reductions. |
(5) |
Adjusted EBITDAX Margin Per Unit is based on actual total amounts rather than the rounded totals presented. |
Free Cash Flow is defined as net cash provided by operating activities less cash paid for capital expenditures. Below is a reconciliation of our Free Cash Flow to our net cash provided by operating activities:
Quarter |
Six months | ||||||
2016 | |||||||
($ in millions) | |||||||
Net cash provided by operating activities |
$ |
301 |
$ |
406 |
|||
Cash paid for capital expenditures |
(179) |
(258) |
|||||
Free Cash Flow |
$ |
122 |
$ |
148 |
|||
Net cash (used in) provided by investing activities
|
$ |
(179) |
$ |
132 |
|||
Net cash used in financing activities |
$ |
(57) |
$ |
(525) |
($ in millions) | |||
Free Cash Flow for the six months ended June 30, 2016 |
$ |
148 |
|
Free Cash Flow for the quarter ended March 31, 2016 |
122 |
||
Free Cash Flow for the quarter ended June 30, 2016 |
$ |
26 |
Cash operating costs is a non-GAAP measure calculated on a per Boe basis as total operating expenses less depreciation, depletion and amortization expense, transportation costs, exploration expense, oil and natural gas purchases, gains and losses on sales of assets and other expenses. Adjusted cash operating costs is a non-GAAP measure calculated as cash operating costs less transition, restructuring and other costs that affect comparability, and the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans).
Below is a reconciliation of our GAAP operating expenses to non-GAAP cash operating costs and adjusted cash operating costs:
Quarter ended June 30, | |||||||||||||||||||||||||||||||||||||||||
2016 |
2015 | ||||||||||||||||||||||||||||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | ||||||||||||||||||||||||||||||||||||||
($ in millions, except per unit costs) | |||||||||||||||||||||||||||||||||||||||||
Total operating expenses |
$ |
127 |
$ |
16.47 |
$ |
397 |
$ |
39.96 | |||||||||||||||||||||||||||||||||
Depreciation, depletion and amortization |
(97) |
(12.67) |
(253) |
(25.46) | |||||||||||||||||||||||||||||||||||||
Transportation costs |
(24) |
(3.19) |
(25) |
(2.56) | |||||||||||||||||||||||||||||||||||||
Exploration expense |
(1) |
(0.12) |
(5) |
(0.59) | |||||||||||||||||||||||||||||||||||||
Oil and natural gas purchases |
(3) |
(0.38) |
(8) |
(0.78) | |||||||||||||||||||||||||||||||||||||
Gain on sale of assets |
82 |
10.77 |
— |
— | |||||||||||||||||||||||||||||||||||||
Total cash operating costs and per-unit cash costs |
$ |
84 |
$ |
10.88 |
$ |
106 |
$ |
10.57 | |||||||||||||||||||||||||||||||||
Transition/restructuring costs, non-cash portion of compensation expense and other(2) |
(5) |
(0.60) |
1 |
0.17 | |||||||||||||||||||||||||||||||||||||
Total adjusted cash operating costs and adjusted per-unit cash operating costs |
$ |
79 |
$ |
10.28 |
$ |
107 |
$ |
10.74 | |||||||||||||||||||||||||||||||||
Total equivalent volumes (MBoe) |
7,691 |
9,920 |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
(2) |
For the quarter ended June 30, 2016, amount includes approximately $2 million of transition and severance costs related to workforce reductions and $3 million of non-cash compensation expense, adjusted for cash payments made on long-term incentive plans of $3 million. For the quarter ended June 30, 2015, amount includes $2 million of non-cash compensation expense, adjusted for cash payments made on long-term incentive plans of $7 million. |
The table below displays the average cash operating costs and adjusted cash operating costs per equivalent unit:
Quarter ended | |||||||||||||
2016 |
2015 | ||||||||||||
Average cash operating costs ($/Boe) |
|||||||||||||
Lease operating expenses |
$ |
4.93 |
$ |
4.72 | |||||||||
Production taxes(1) |
1.54 |
2.05 | |||||||||||
General and administrative expenses(2) |
4.20 |
3.56 | |||||||||||
Taxes, other than production and income taxes |
0.21 |
0.24 | |||||||||||
Total cash operating costs |
$ |
10.88 |
$ |
10.57 | |||||||||
Transition/restructuring costs, non-cash portion of compensation expense and other(2) |
(0.60 |
0.17 | |||||||||||
Total adjusted cash operating costs |
$ |
10.28 |
$ |
10.74 |
(1) |
Production taxes include ad valorem and severance taxes. |
(2) |
For additional detail of adjusted items, which are part of general and administrative expenses, refer to the reconciliation of cash operating costs and adjusted cash operating costs above. |
Net debt is a non-GAAP measure defined as long-term debt less cash and cash equivalents. At December 31, 2015, the company's net debt was approximately $4.9 billion (total debt of approximately $4,869 million less cash and cash equivalents of approximately $26 million). At June 30, 2016, the company's net debt was approximately $3.9 billion (total debt of approximately $3,970 million less cash and cash equivalents of approximately $39 million).
We believe that the presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Margin Per Unit is important to provide management and investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business without regard to financing methods and capital structure, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. We believe that the presentation of Free Cash Flow is important because it provides management and investors with useful additional information for analysis of the company's ability to internally fund capital expenditures and to service or incur additional debt. We believe that the presentation of Cash Operating Costs and Adjusted Cash Operating Costs per unit provides management and investors valuable measures of operating performance and efficiency relative to other industry participants and relative to our historical results. We believe Net Debt provides useful information to investors for analysis of the Company's financial position and/or liquidity. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Free Cash Flow, Cash Operating Costs, Adjusted Cash Operating Costs and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP or as an alternative to net income (loss), operating income (loss), earnings (loss) per share, operating or investing cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. For example, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Free Cash Flow, Cash Operating Costs, Adjusted Cash Operating Costs and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Free Cash Flow, Cash Operating Costs, and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual items, or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
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SOURCE EP Energy Corporation
HOUSTON, July 26, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Thursday, August 4, to discuss its second quarter 2016 financial and operational results. The company's second quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, August 3, 2016.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 3596277) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through September 2, 2016 on the company's website in the Investor Center (conference ID# 10089555). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in all phases of the E&P value chain—exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, July 20, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) today announced it has significantly increased its 2017 oil hedge positions and added 2016 natural gas hedges.
The company now has a weighted average price floor of $62.34 per barrel (Bbl) on approximately 12.8 million barrels (MMBbl) of oil in 2017. Based on the mid-point of 2016 guidance, this would equate to approximately 75 percent of estimated annual 2017 oil production.
The 2017 oil hedges utilize a combination of fixed price swaps of $66 per Bbl and three-way collar contracts of $46x$61x$70 per Bbl which together establish improved downside price protection, while providing upside price participation if oil prices recover.
In addition, EP Energy added 2016 natural gas positions which effectively hedge approximately 60 percent of its remaining estimated 2016 natural gas production at $3.39 per million British thermal units (MMBtu).
The company's hedge position as of June 30, 2016 is detailed in the table below:
2016 |
2017 | |
Oil |
||
Fixed price swap volumes (MMBbls) |
7.8 |
4.0 |
Three-way collar volumes (MMBbls) |
8.8 | |
Total hedged volumes |
7.8 |
12.8 |
Average floor price ($/Bbl) |
$ 80.67 |
$ 62.34 |
Natural Gas |
||
Fixed price swap volumes (TBtu) |
11.3 |
- |
Average floor price ($/MMBtu) |
$ 3.39 |
- |
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in all phases of the E&P value chain—exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
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SOURCE EP Energy Corporation
HOUSTON, May 4, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE:EPE) today reported first quarter 2016 financial and operational results.
First quarter 2016 results
Significant progress in reducing debt and increasing financial flexibility
"In the first quarter we delivered solid results from operations. We continue to drive down costs while improving well performance," said Brent Smolik, chairman, president, and chief executive officer of EP Energy Corporation. "Our top priorities for 2016 are to improve liquidity and reduce leverage. We've made good progress on both. In the first quarter, we generated $122 million of free cash flow. In May, we closed the Haynesville asset sale, increasing liquidity by approximately $250 million, net of the corresponding borrowing base reduction. To date, we have executed repurchases of $609 million principal amount of debt for $287 million, capturing $322 million of discounts and approximately $50 million of annualized interest savings. We also reached agreement with our bank group to reset our borrowing base at $1.65 billion, with much improved covenant flexibility through early 2018. We remain well positioned to benefit as commodity prices improve."
EP Energy reported $0.19 Adjusted EPS and $0.80 Discretionary Cash Flow Per Share for the first quarter of 2016. Adjusted EBITDAX for the first quarter of 2016 was $278 million, down from $366 million in the first quarter of 2015, due primarily to lower oil production volumes and lower realized pricing, partially offset by lower operating costs. Total adjusted cash operating costs for the quarter ended March 31, 2016 were $8.71 per Boe, well below $11.44 per Boe for the first quarter of 2015, due primarily to lower general and administrative costs, lower production taxes, and lower lease operating costs related to continued operational efficiencies and cost reductions.
During the quarter, the company's activity levels were significantly reduced compared to the same period in 2015. Total capital expenditures in the first quarter of 2016 were $132 million, with more than half invested in the company's Eagle Ford program. During the first quarter of 2016, the company completed 23 wells. Average daily oil production decreased 15 percent to 50.8 MBbls/d, down from 60.0 MBbls/d in the first quarter of 2015. Total equivalent production grew to 104 thousand barrels of oil equivalent per day (MBoe/d), up from 102.4 MBoe/d in the same period last year.
Note: See Disclosure of Non-GAAP Financial Measures section of this release for applicable definitions and reconciliations to GAAP terms.
Liquidity and Liability Management
In the first quarter of 2016, EP Energy generated free cash flow of $122 million, continuing the trend from the second half of 2015.
On May 2, the company completed its semi-annual borrowing base redetermination with the value reset to $1.65 billion from the previous value of $2.75 billion. The reduced value is primarily due to significantly lower bank commodity price forecasts, the sale of Haynesville assets and the roll-off of certain hedge positions.
As part of the redetermination process, EP Energy executed a covenant amendment to provide additional future flexibility. The amendment included replacing the 4.5 times debt to EBITDAX covenant with a 3.5 times first lien debt to EBITDAX covenant through the first quarter of 2018.
The company began repurchasing debt in the open-market in February 2016. As of May 4, 2016, the company had executed repurchases of $609 million of face value debt for $287 million in cash. The company expects to reduce annualized interest expense by approximately $50 million as a result of the debt repurchases and retirement.
In the first quarter of 2016, EP Energy announced its agreement to divest its Haynesville assets for approximately $420 million subject to customary closing adjustments. The transaction closed on May 3. The cash proceeds were used to pay down borrowings on the company's RBL Facility. The divestiture provided additional liquidity by eliminating $60 million in letters of credit and reduces future transportation commitments by $106 million.
As of March 31, 2016, EP Energy had liquidity of approximately $800 million and net debt of $4.0 billion pro forma for the borrowing base redetermination, Haynesville asset divestiture and open-market debt repurchases to date.
Eagle Ford Program
In the first quarter of 2016, the company completed 16 wells across its Eagle Ford program with oil production of 32.4 MBbls/d, a 15 percent decrease compared with the first quarter of 2015. Oil production declined primarily due to lower activity levels in the latter part of 2015 and in the quarter. Downtime at a third-party processing plant in South Texas also negatively affected production. Total equivalent production was 50.8 MBoe/d.
The company is currently running one rig in the program and remains focused on further well and lifting costs reductions along with enhancing lateral placement and completion optimization.
Wolfcamp Program
In the first quarter of 2016, the company completed five wells in its Wolfcamp program and produced 7.0 MBbls/d of oil, down 26 percent from the same period in 2015. Oil production declined primarily due to lower activity levels in the latter part of 2015 and in the quarter. EP Energy is encouraged by early results from the five wells drilled in Reagan County, which included three completions in the A-bench. Total equivalent production for the first quarter of 2016 was 18.3 MBoe/d.
The company has no current drilling rigs running in the Wolfcamp. All Wolfcamp completions in the first half of 2016 will come from its drilled and uncompleted (DUC) well inventory.
Altamont Program
In the first quarter of 2016, EP Energy completed two wells in its Altamont program, and oil production was 11.4 MBbls/d, a 9 percent decrease compared with the same period in 2015. Oil production declined primarily due to lower activity levels, partially offset by the company's increased focus on its recompletion program. Altamont total equivalent production was 16.2 MBoe/d.
The company commenced its drilling partnership in March and will have one rig running through 2016.
In the first quarter of 2016, realized pricing in the program improved relative to WTI compared to the same period in 2015.
Multi-year Commodity Hedge Program
EP Energy maintains a solid hedge program, which provides substantial near-term commodity price protection. Year-to-date through the first quarter, the company has realized $212 million of settlements on its financial derivatives.
A summary of the company's open hedge positions is listed below:
2016 |
2017 |
||||||||
Total Fixed Price Hedges |
|||||||||
Oil volumes (MMBbls)(1) |
10.5 |
5.1 |
|||||||
Average floor price ($/Bbl) |
$ |
80.29 |
$ |
65.87 |
|||||
Natural gas volumes (TBtu) |
5.5 |
— |
|||||||
Average floor price ($/MMBtu) |
$ |
4.20 |
$ |
— |
Note: Positions are as of March 31, 2016 (Contract months: April 2016 - Forward). |
(1) 2017 positions include WTI three way collars of 1.1 MMBbls. |
In addition to the 2016 positions above, the company entered into offsetting contracts to lock-in a portion of its oil hedge gains during the quarter. As a result of these contracts, EP Energy will receive an approximate $40 per barrel spread, in addition to LLS index settlement prices, on 3.1 MMBbls for the remainder of 2016.
At March 31, 2016, the mark-to-market value of the company's hedge contracts was approximately $600 million including the value of the offsetting contracts.
Updated 2016 Outlook
EP Energy continues to manage to positive free cash flow for the full year. The company updated its 2016 outlook to reflect its Haynesville asset sale which closed on May 3, 2016. No additional changes have been made to the original guidance.
If current commodity pricing persists throughout the year, the company expects 2016 capital spending and activity levels to be at the low end of its guidance. At the mid-point of the company's guidance, capital and completion activity is back-end loaded, with one-third of its capital budget spent in the first half of 2016 and two-thirds spent in the second half of 2016.
Original Guidance (February) |
Updated Guidance (May) | |||
Capital program ($ million) |
$500 - $900 |
$500 - $900 | ||
Production |
||||
Total production (MBoe/d) |
91 - 97 |
81 - 88 | ||
Oil production (MBbls/d) |
45 - 50 |
45 - 50 | ||
Well completions |
75 - 160 |
75 - 160 | ||
Adjusted cash operating costs (per Boe) |
$9.50 - $10.50 |
$10.40 - $11.40 | ||
Transportation cost (per Boe) |
$3.40 - $3.65 |
$3.30 - $3.40 | ||
DD&A (per Boe) |
N/A |
$13.00 - $14.00 |
Detailed financial and operational information for the company will be posted at www.epenergy.com in the Investor Center section.
Webcast Information
EP Energy has scheduled a webcast at 11:00 a.m. Eastern Time, 10:00 a.m. Central Time, on May 5, to discuss its first quarter financial and operational results. The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 6769250) 10 minutes prior to the start of the webcast. A replay of the webcast will be available through Friday, June 3, 2016 on the company's website in the Investor Center (conference ID# 10084112).
About EP Energy
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in a number of the country's leading unconventional resource areas. EP Energy is active in all phases of the E&P value chain—exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP.
Non-GAAP Terms
Adjusted EPS is defined as diluted earnings per share adjusted for certain items that EP Energy considers to be significant to understanding our underlying performance for a given period. Adjusted EPS is useful in analyzing the company's ongoing earnings potential and understanding certain significant items impacting the comparability of EP Energy's results. Adjusted EPS is net income (loss) per common share adjusted for the impact of financial derivatives (mark-to-market effects of financial derivatives, net of settlements and cash premiums paid or received related to these derivatives), gains on extinguishment of debt, other non-recurring costs, including transition and restructuring charges and changes in the valuation allowance on deferred tax assets.
Below is a reconciliation of Adjusted EPS to our consolidated diluted net income per share:
Quarter ended March 31, 2016 | |||||||||||
Pre Tax |
After Tax |
Diluted EPS | |||||||||
($ in millions, except earnings per share amounts) | |||||||||||
Net income |
$ |
94 |
$ |
0.38 |
|||||||
Adjustments(1) |
|||||||||||
Impact of financial derivatives(2) |
$ |
170 |
$ |
109 |
$ |
0.44 |
|||||
Transition, restructuring and other costs(3) |
8 |
5 |
0.02 |
||||||||
Gain on extinguishment of debt |
(196) |
(126) |
(0.51) |
||||||||
Valuation allowance on deferred tax assets |
(35) |
(0.14) |
|||||||||
Total adjustments |
$ |
(18) |
$ |
(47) |
$ |
(0.19) |
|||||
Adjusted EPS |
$ |
0.19 |
|||||||||
Diluted weighted average shares |
248 |
(1) |
All individual adjustments for all periods presented assume a statutory federal and blended state tax rate, as well as any other income tax effects specifically attributable to that item. |
(2) |
Represents mark-to-market impact net of settlements and cash premiums related to financial derivatives. |
(3) |
Reflects approximately $8 million for transition and severance costs related to restructuring activities. |
EBITDAX is defined as net income (loss) plus interest and debt expense, income taxes, depreciation, depletion and amortization and exploration expense. Adjusted EBITDAX is defined as EBITDAX, adjusted as applicable in the relevant period for the net change in the fair value of derivatives (mark-to-market effects of financial derivatives, net of settlements and cash premiums paid or received related to these derivatives), the non-cash portion of compensation expense (which represents non-cash compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans), transition, restructuring and other non-recurring costs and gains on extinguishment of debt. Adjusted EBITDAX Margin Per Unit is calculated using Adjusted EBITDAX divided by equivalent volumes.
Below is a reconciliation of our EBITDAX and Adjusted EBITDAX to our consolidated net income:
Quarter ended | |||||||
2016 |
2015 | ||||||
($ in millions, except equivalent volumes and per unit) | |||||||
Net income |
$ |
94 |
$ |
19 |
|||
Income tax expense |
— |
10 |
|||||
Interest expense, net of capitalized interest |
84 |
84 |
|||||
Depreciation, depletion and amortization |
113 |
224 |
|||||
Exploration expense |
1 |
5 |
|||||
EBITDAX |
292 |
342 |
|||||
Mark-to-market on financial derivatives(1) |
(42) |
(203) |
|||||
Settlements and cash premiums on financial derivatives(2) |
212 |
214 |
|||||
Non-cash portion of compensation expense(3) |
4 |
5 |
|||||
Transition, restructuring and other costs(4) |
8 |
8 |
|||||
Gain on extinguishment of debt |
(196) |
— |
|||||
Adjusted EBITDAX |
$ |
278 |
$ |
366 |
|||
Total equivalent volumes (MBoe) |
9,466 |
9,218 |
|||||
Adjusted EBITDAX Margin Per Unit (MBoe)(5) |
$ |
29.37 |
$ |
39.73 |
(1) |
Represents the income statement impact of financial derivatives. |
(2) |
Represents actual settlements related to financial derivatives, including cash premiums. There were no cash premiums received or paid for the periods presented. |
(3) |
For both of the quarters ended March 31, 2016 and 2015, cash payments were less than $1 million. |
(4) |
Reflects approximately $8 million in both quarters ended March 31, 2016 and 2015 for transition and severance costs related to restructuring activities. |
(5) |
Adjusted EBITDAX Margin Per Unit is based on actual total amounts rather than the rounded totals presented. |
Discretionary Cash Flow and Discretionary Cash Flow Per Share are non-GAAP measures calculated using net income (loss) adjusted for certain items including depreciation, depletion and amortization, the impact of financial derivatives (mark-to-market effects of financial derivatives, net of settlements and cash premiums paid or received related to these derivatives), transition, restructuring and other non-recurring costs, deferred income taxes, non-cash exploration expense, gains on extinguishment of debt, and other non-cash income items.
Below is a reconciliation of Discretionary Cash Flow to our consolidated net income and operating cash flow:
Quarter ended |
||||
2016 |
||||
($ in millions) |
||||
Net income |
$ |
94 |
||
Depreciation, depletion and amortization |
113 |
|||
Impact of financial derivatives(1) |
170 |
|||
Transition, restructuring and other costs(2) |
8 |
|||
Gain on extinguishment of debt |
(196) |
|||
Other non-cash income items |
9 |
|||
Discretionary Cash Flow |
$ |
198 |
||
Discretionary Cash Flow Per Share(3) |
$ |
0.80 |
||
Discretionary Cash Flow |
$ |
198 |
||
Transition, restructuring and other costs(2) |
(8) |
|||
Working capital and other changes |
111 |
|||
Net cash provided by operating activities |
$ |
301 |
(1) |
Represents mark-to-market impact net of settlements and cash premiums related to financial derivatives. |
(2) |
Reflects approximately $8 million for transition and severance costs related to restructuring activities. |
(3) |
Reflects fully diluted weighted average shares of approximately 248 million. |
Free Cash Flow is defined as net cash provided by operating activities less cash paid for capital expenditures. Below is a reconciliation of our Free Cash Flow to our net cash provided by operating activities:
Quarter ended |
||||
2016 |
||||
($ in millions) |
||||
Net cash provided by operating activities |
$ |
301 |
||
Cash paid for capital expenditures |
(179) |
|||
Free Cash Flow |
$ |
122 |
Cash operating costs is a non-GAAP measure calculated on a per Boe basis and includes total operating expenses less depreciation, depletion and amortization expense, transportation costs, exploration expense, oil and natural gas purchases and other expenses. Adjusted cash operating costs is a non-GAAP measure and is defined as cash operating costs less transition, restructuring and other non-recurring costs, and the non-cash portion of compensation expense (which represents compensation expense under our long-term incentive programs adjusted for cash payments made under our long-term incentive plans).
Below is a reconciliation of our cash operating costs and adjusted cash operating costs to our operating expenses:
Quarter ended March 31, | ||||||||||||||||
2016 |
2015 | |||||||||||||||
Total |
Per-Unit(1) |
Total |
Per-Unit(1) | |||||||||||||
($ in millions, except per unit costs) | ||||||||||||||||
Total operating expenses |
$ |
242 |
$ |
25.61 |
$ |
380 |
$ |
41.27 |
||||||||
Depreciation, depletion and amortization |
(113) |
(11.94) |
(224) |
(24.30) |
||||||||||||
Transportation costs |
(30) |
(3.11) |
(27) |
(2.90) |
||||||||||||
Exploration expense |
(1) |
(0.13) |
(5) |
(0.51) |
||||||||||||
Oil and natural gas purchases |
(4) |
(0.46) |
(7) |
(0.74) |
||||||||||||
Total cash operating costs and per-unit cash costs |
$ |
94 |
$ |
9.97 |
$ |
117 |
$ |
12.82 |
||||||||
Transition/restructuring costs, non-cash portion of compensation expense and other(2) |
(12) |
(1.26) |
(12) |
(1.38) |
||||||||||||
Total adjusted cash operating costs and adjusted per-unit cash operating costs |
$ |
82 |
$ |
8.71 |
$ |
105 |
$ |
11.44 |
||||||||
Total equivalent volumes (MBoe) |
9,466 |
9,218 |
(1) |
Per unit costs are based on actual total amounts rather than the rounded totals presented. |
(2) |
For the quarter ended March 31, 2016, amount includes approximately $8 million of transition and severance costs related to restructuring and $4 million of non-cash compensation expense, adjusted for cash payments made of less than $1 million. For the quarter ended March 31, 2015, amount includes $8 million of transition and severance costs related to restructuring and $5 million of non-cash compensation expense, adjusted for cash payments made of less than $1 million. |
The table below displays the average cash operating costs and adjusted cash operating costs per equivalent unit:
Quarter ended | |||||||
2016 |
2015 | ||||||
Average cash operating costs ($/Boe) |
|||||||
Lease operating expenses |
$ |
4.38 |
$ |
5.12 |
|||
Production taxes(1) |
1.27 |
2.13 |
|||||
General and administrative expenses(2) |
4.04 |
5.09 |
|||||
Taxes, other than production and income taxes |
0.28 |
0.28 |
|||||
Other expenses(3) |
— |
0.20 |
|||||
Total cash operating costs |
$ |
9.97 |
$ |
12.82 |
|||
Transition/restructuring costs, non-cash portion of compensation expense and other(2) |
(1.26) |
(1.38) |
|||||
Total adjusted cash operating costs |
$ |
8.71 |
$ |
11.44 |
(1) |
Production taxes include ad valorem and severance taxes. |
(2) |
For additional detail of adjusted items, which are part of general and administrative expenses, refer to the reconciliation of cash operating costs and adjusted cash operating costs above. |
(3) |
Includes early rig termination fees of $2 million incurred during the first quarter of 2015. |
Net debt is defined as long-term debt less cash and cash equivalents and provides useful information to investors for analysis of the company's debt position net of cash that can be immediately available to reduce such balances. At December 31, 2015 the company's long-term debt was $4,869 million and cash and cash equivalents was $26 million. At March 31, 2016 the company's net debt was approximately $4.5 billion (total debt of approximately $4.6 billion less cash and cash equivalents of approximately $0.1 billion). Pro forma net debt of approximately $4.0 billion as of March 31, 2016 reflects net reductions of approximately $0.5 billion primarily for the Haynesville divestiture and open-market debt repurchases.
We believe that the presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX and Adjusted EBITDAX Margin Per Unit is important to provide management and investors with additional information (i) to evaluate our ability to service debt adjusting for items required or permitted in calculating covenant compliance under our debt agreements, (ii) to provide an important supplemental indicator of the operational performance of our business, (iii) for evaluating our performance relative to our peers, (iv) to measure our liquidity (before cash capital requirements and working capital needs) and (v) to provide supplemental information about certain material non-cash and/or other items that may not continue at the same level in the future. We believe that the presentation of Discretionary Cash Flow, Discretionary Cash Flow Per Share and Free Cash Flow is important because it provides management and investors with useful additional information for analysis of the company's ability to internally generate funds for exploration, development and acquisitions as well as adjusting net income (loss) for unusual items to allow for a more consistent comparison from period to period. We believe that the presentation of Cash Operating Costs and Adjusted Cash Operating Costs per unit provides management and investors valuable measures of operating performance and efficiency. In addition, the company believes that these measures are widely used by professional research analysts and others in the valuation, comparison and investment recommendations of companies in the oil and gas exploration and production industry.
Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Discretionary Cash Flow, Discretionary Cash Flow Per Share, Free Cash Flow, Cash Operating Costs, Adjusted Cash Operating Costs and Net Debt have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under U.S. GAAP or as an alternative to net income (loss), operating income (loss), earnings (loss) per share, operating cash flows or other measures of financial performance or liquidity presented in accordance with GAAP. For example, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Discretionary Cash Flow, Discretionary Cash Flow Per Share, Free Cash Flow, Cash Operating Costs, Adjusted Cash Operating Costs and Net Debt may not be comparable to similarly titled measures used by other companies in our industry. Furthermore, our presentation of Adjusted EPS, EBITDAX, Adjusted EBITDAX, Adjusted EBITDAX Margin Per Unit, Discretionary Cash Flow, Discretionary Cash Flow Per Share, Free Cash Flow, Cash Operating Costs, and Adjusted Cash Operating Costs should not be construed as an inference that our future results will be unaffected by the items noted above or what we believe to be other unusual or non-recurring items or that in the future we may not incur expenses that are the same as or similar to some of the adjustments in this presentation.
Cautionary Statement Regarding Forward-Looking Statements
This release includes certain forward-looking statements and projections of EP Energy. We have made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed, including, without limitation, the volatility of and current sustained low oil, natural gas and NGL prices, the supply and demand for oil, natural gas and NGLs; changes in commodity prices and basis differentials for oil and natural gas; the company's ability to meet production volume targets; the uncertainty of estimating proved reserves and unproved resources; the future level of service and capital costs; the availability and cost of financing to fund future exploration and production operations; the success of drilling programs with regard to proved undeveloped reserves and unproved resources; the company's ability to comply with the covenants in various financing documents; the company's ability to obtain necessary governmental approvals for proposed E&P projects and to successfully construct and operate such projects; actions by the credit rating agencies; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers; general economic and weather conditions in geographic regions or markets served by the company, or where operations of the company are located, including the risk of a global recession and negative impact on oil and natural gas demand; the uncertainties associated with governmental regulation, including any potential changes in federal and state tax laws and regulations; and other factors described in the company's Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. EP Energy assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by EP Energy, whether as a result of new information, future events, or otherwise.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy Corporation
HOUSTON, April 27, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 11 a.m. Eastern Time, 10 a.m. Central Time, on Thursday, May 5, to discuss its first quarter 2016 financial and operational results. The company's first quarter earnings press release is scheduled to be issued after the New York Stock Exchange closes trading on Wednesday, May 4, 2016.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 6769250) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through June 3, 2016 on the company's website in the Investor Center (conference ID# 10084112). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multi-year drilling opportunities, and a strategic presence in fast-emerging unconventional resource areas. EP Energy is active in all phases of the E&P value chain—exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy Corporation
HOUSTON, Feb. 17, 2016 /PRNewswire/ -- EP Energy Corporation (NYSE: EPE) has scheduled a webcast at 10 a.m. Eastern Time, 9 a.m. Central Time, on Friday, February 19, to discuss its fourth quarter and full year 2015 financial and operational results.
The webcast may be accessed online through the company's website at epenergy.com in the Investor Center. Materials to be discussed during the webcast will be available in the Investor Center one hour prior to the webcast. A limited number of telephone lines will be available to participants by dialing 888-317-6003 (conference ID# 0434904) 10 minutes prior to the start of the webcast.
A replay of the webcast will be available through March 21, 2016 on the company's website in the Investor Center (conference ID# 10079677). If you have any questions regarding the dial-in procedures, please contact Bill Baerg at 713-997-2906.
The EP Energy team has a passion for finding and producing the oil and natural gas that enriches people's lives. As a leading North American oil and natural gas producer, EP Energy has a proven strategy, a significant reserve base, multiyear drilling opportunities, and a strategic presence in fastemerging unconventional resource areas. EP Energy is active in all phases of the E&P value chain-exploring for, acquiring, developing and producing oil and natural gas. For more information about EP Energy, visit epenergy.com.
Contact
Investor and Media Relations
Bill Baerg
713-997-2906
bill.baerg@epenergy.com
Logo - http://photos.prnewswire.com/prnh/20140205/DA59609LOGO
SOURCE EP Energy Corporation
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