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EPL Announces Fourth Quarter and Year-End Results for 2012

EPL Announces Fourth Quarter and Year-End Results for 2012  NEW ORLEANS, March 7, 2013 (GLOBE NEWSWIRE) -- EPL Oil & Gas, Inc. (EPL or the Company) (NYSE:EPL) today reported financial and operational results for the fourth quarter and full year 2012.  Highlights    *4Q2012 EBITDAX of $95.5 million and net income of $24.2 million ($0.61 per     diluted share) respectively. 2012 EBITDAX of $285.9 million, slightly     above the Company's guidance range (see EBITDAX reconciliation in the     tables). 2012 Net income of $58.8 million ($1.50 per diluted share)   *4Q12 oil production rose 43% versus 4Q11 to 13,516 Barrels of oil per day     (Bopd) in line with guidance reflecting the impact of the Hilcorp     acquisition production only since October 31, 2012 close.   *2012 exit oil production estimated at 16,500 Bopd, with 1Q2013 and full     year 2013 oil production guidance at 16,000 to 17,000 Bopd and 17,000 to     18,500 Bopd, respectively   *Estimated proved reserves of 77.4 Mmboe as of December 31, 2012,     representing an annual increase of 109% mainly through acquisitions and     organic production replacement of 187% at an average cost of $26/Boe.   *Year-end 2012 PV-10 estimated at $2.0 billion for 1P reserves using SEC     prices (see discussion of PV-10 in the appendix)   *2013 capital budget remains at $300 million, up 34% over 2012 and     dominated by oil projects intended to drive both production and organic     reserve growth   *Continued focus on free cash flow and balance sheet strength: current net     debt to projected 2013 EBITDAX estimated at 1.4x and expected to decrease     to 1.3x post-close of the currently-pending Bay Marchand (BM) non-operated     asset sale for $51.5 million. Post close liquidity in the form of cash     plus undrawn revolver availability estimated at $290 million  Financial Results  Revenue for the fourth quarter of 2012 was $138.9 million, compared to $103.4 million for the same period a year ago, driven by higher realized oil production from the Company's focus on oil-weighted development projects.For full year 2012, revenues increased 22% to $423.6 million versus $348.3 million for full year 2011, due to a 29% increase in 2012 annual oil production, offset by a 3% decrease in oil prices.  For the fourth quarter of 2012, EPL reported net income to common stockholders of $24.2 million, or $0.61 per diluted share, compared to a net loss of $7.3 million, or $0.19 per diluted share, for the same period a year ago. The net income for the fourth quarter of 2012 included $1.4 million of non-cash unrealized losses on derivative instruments, $2.7 million of non-cash costs attributable to property impairments related to gas properties offset by a $1.0 million gain on abandonment activities. Excluding the impact of these non-cash items, EPL's adjusted fourth quarter net income, a non-GAAP measure, would have been $26.2 million, or $0.67 per diluted share.  For full year 2012, net income was $58.8 million, or $1.50 per diluted share, compared to net income of $26.6 million, or $0.66 per diluted share for full year 2011. The net income for 2012 was impacted by $9.5 million of non-cash unrealized losses on derivative instruments offset by $8.9 million of non-cash costs attributable to property impairments and a $2.4 million loss on abandonment activities related mainly to gas properties. Excluding the impact of these non-cash items, EPL's adjusted 2012 net income, a non-GAAP measure, would have been $72.1 million, or $1.85 per diluted share.  For the fourth quarter of 2012, EBITDAX was $95.5 million and discretionary cash flow was $84.5 million, or $2.17 per share (see reconciliation to GAAP of EBITDAX and discretionary cash flow in the tables). Cash flow from operating activities in the fourth quarter of 2012 was $51.3 million, a 22% decrease compared to cash flow from operating activities for the same quarter a year ago.  For full year 2012, EBITDAX was $285.9 million and discretionary cash flow was $264.8 million, or $6.78 per share (see reconciliation to GAAP of EBITDAX and discretionary cash flow in the tables). Cash flow from operating activities in 2012 was $213.9 million, a 25% increase over cash flow from operating activities for 2011.  Gary C. Hanna, the Company's President and CEO, stated, "2012 was a transformational year that delivered on all of our stated goals as we continued our focus on implementing our acquire and exploit strategy.In just a few short years, we have turned the corner on a host of operational initiatives, including transforming from a gas driven company into being oil-rich and achieving substantial growth in terms of production, reserves, and upside opportunities.  "With the integration of the Hilcorp acquisition behind us and with approximately 340,000 net leasehold acres on the Shelf, we are focused squarely on the future upside potential of our expanded asset base. With our regional expertise, we will continue to focus on operational and technical excellence as we extract organic production and reserve growth from our high quality acreage. With our substantial liquidity, continued free cash flow generation and balanced acquire and exploit strategy, we also intend to continue executing on additional prudent acquisition targets to accelerate our growth and provide additional opportunity sets."  Production and Price Realizations  Oil production for the fourth quarter of 2012 averaged 13,516 Barrels (Bbls) per day, which was within the Company's guidance range and a new record high for the Company. Fourth quarter 2012 oil production volumes were 43% higher than in the comparable quarter last year, primarily as a result of the recent Hilcorp acquisition of oil-weighted properties that closed October 31, 2012 and the continued focus on oil-weighted projects.2012 exit oil production for the combined asset base was estimated at 16,500 Bbls per day.  Natural gas production averaged 28.2 million cubic feet (Mmcf) per day in the fourth quarter of 2012, which was slightly above the Company's guidance range.EPL has continued its focus on oil development opportunities which have higher revenue generation capability than natural gas.  Price realizations for the fourth quarter of 2012, all of which are stated before the impact of derivative instruments, averaged $106.07 per barrel for crude oil and $3.40 per thousand cubic feet (Mcf) of natural gas, compared to $116.40 per barrel of crude oil and $3.19 per Mcf of natural gas in the same quarter a year ago. The Company's crude oil is advantaged by receiving Heavy Louisiana Sweet and Light Louisiana Sweet crude oil basis differentials.  Oil production for 2012 averaged 10,398 Bbls per day and natural gas production averaged 17.9 Mmcf per day. Price realizations for the full year, all of which are stated before the impact of derivative instruments, averaged $108.88 per barrel for crude oil and $2.89 per Mcf of natural gas, compared to $110.82 per barrel of crude oil and $4.11 per Mcf of natural gas in 2011.  Operating Expenses  Lease operating expenses (LOE) for the fourth quarter of 2012 totaled $32.8 million, while general and administrative (G&A) expenses were $6.2 million. LOE for 2012 totaled $94.9 million, while G&A expenses were $23.2 million for the same period. Reported LOE and G&A increased over the same periods a year ago mainly due to property acquisitions concluded during the year. G&A expenses included non-cash stock based compensation recorded in the fourth quarter and full year 2012 of $1.2 million and $4.7 million, respectively.  Capital Expenditures and P&A Operations  For full year 2012, costs incurred for development and exploration activities totaled approximately $212.5 million and $10.6 million on seismic purchases, for a total expenditure of $223.1 million. During the year, the Company completed 28 operations, including 12 successful sidetracks and drillwells and 16 successful workovers, with an overall 90% success rate. Additionally, the Company spent $7.4 million on 6 bid leases comprising 27,148 acres in the shallow Gulf of Mexico (GOM) shelf.  The Company had organic reserve additions from its capital activities totaling 8.1 million barrels of oil equivalent (Mmboe) of proved reserves of which 6.4 million barrels were oil. 2012 finding and development costs associated with these activities were approximately $26.23 per Boe on a proved reserve basis. All of the wells were brought on line during 2012 and some more recently in 2013.Probable reserves associated with these activities and other wells throughout EPL's entire reserve base are currently being quantified by the Company's outside engineering firm and will be available in the coming months.  In addition, the Company spent approximately $35 million in 2012 for plugging and abandonment and other decommissioning activities performed during the year, which will serve to reduce future maintenance and insurance costs.In total, since the Company began focusing its efforts to reduce its idle iron in late 2009, the Company has plugged and abandoned 428 wells and decommissioned 157 jackets and platforms.  Year-End 2012 Proved Reserves  The Company's estimated proved reserves as of December 31, 2012 were 77.4 Mmboe (61% oil), representing an increase of 109% compared to estimated proved reserves of 37.1 Mmboe as of December 31, 2011. At year-end 2012, 58.0 Mmboe (or 75%) of these proved reserves were proved developed reserves, 65% of which were oil. Estimated proved undeveloped reserves (PUDs) at year-end 2012 were 19.4 Mmboe, 49% of which were oil.  The net increase in total estimated proved reserves was the result of increases from acquisitions of 35.7 Mmboe, organic reserve additions from extensions and discoveries of 8.1 Mmboe, positive revisions of 1.8 Mmboe, offset by 5.3 Mmboe of net production. Organic additions and revisions replaced 187% of 2012 net production (see the Supplemental Oil & Gas Disclosure table for details).  The present value of the future net cash flows before income taxes of the Company's estimated proved oil and natural gas reserves at the end of 2012 using a discount rate of 10% (PV-10) was approximately $2.0 billion as calculated consistent with SEC guidelines and pricing. All development, P&A and decommissioning costs are included in the calculation of PV-10. (PV-10 is a non-GAAP measure; see table below and discussion of PV-10 in the appendix.)  All of the Company's proved reserve figures are based upon third party engineering estimates prepared by Netherland, Sewell & Associates, Inc. and W.D. Von Gonten & Co.  1P RESERVES AND PV-10 VALUES                                                                        ReserveCategory      Oil(Mmbo)    Gas (Bcf)    Mmboe   PV10 YE                                                                     ($Billion)^(1) Proved Developed      37.9          120.7        58.0    1.5                Proved Undeveloped    9.5           59.3         19.4    0.5                Proved (1P)           47.4          179.9        77.4    2.0                                                                                       (1) The present value of the future net cash flows before income taxes of the Company's estimated proved oil and natural gas reserves at the end of 2012 using a discount rate of 10% (PV-10) as calculated consistent with SEC guidelines and 2012 pricing of $105.13 per barrel of oil and $2.92 per Mcf of natural gas.  Acreage  At year-end 2012, EPL's gross developed leasehold acreage totaled 343,366 acres and gross acreage totaled 528,532 acres.Net developed leasehold acreage and total net leasehold acreage were 243,972 and 367,880 acres, respectively.Ninety-four percent of the combined undeveloped and developed net leasehold acreage is located on the GOM shelf, and the remaining 6% is primarily undeveloped deepwater GOM acreage.  Liquidity and Capital Resources  As of December 31, 2012, the Company had unrestricted cash on hand of $1.5 million and restricted cash of $6.0 million. On October 31, 2012, in connection with the closing of the Hilcorp Acquisition, EPL's senior credit facility was amended and restated, expanding the facility from $250 million to $750 million and increasing the borrowing base from $200 million to $425 million.The Hilcorp Acquisition was financed with cash on hand, the net proceeds from the sale of $300 million in aggregate principal amount of the 8.25% senior notes due 2018 and borrowings of $205 million under the senior credit facility. As of February 28, 2013, EPL had reduced its borrowing under the senior credit facility to $185.0 million outstanding and had substantial liquidity of $240.0 million available under the facility. Based on its total current debt level, EPL's leverage is at 1.4x debt to projected 2013 EBITDAX using the midpoint of guidance (see the guidance section contained in this press release and the discussion of EBITDAX in the tables).  As recently announced, EPL has executed a purchase and sale agreement to sell certain shallow water GOM shelf oil and natural gas interests located within the non-operated BM field area to the well-established property operator for $51.5 million in cash and the buyer's assumption of liabilities currently recorded on EPL's balance sheet of $10.8 million resulting in total consideration of $62.3 million, subject to customary adjustments to reflect the January 1, 2013 economic effective date. The assets are currently producing approximately 400 Boe per day, about 97% of which are oil. Estimated proved reserves as of the January 1, 2013 economic effective date totaled approximately 1.6 million Boe, 90% of which are oil. The total proved divestiture PV-10 value is estimated at $53 million using the estimated proved reserves and strip pricing as of year-end 2012 (see discussion of PV-10 in the appendix). From time to time, EPL may decide to divest of certain assets that do not meet its capital expenditure risk, rate of return, operational control or other criteria in an effort to high-grade its overall portfolio of assets.  As also previously reported, EPL's lenders have confirmed that, following the sale, EPL's borrowing base under its senior secured credit facility will be unchanged at $425 million.EPL projects liquidity, in the form of cash plus undrawn revolver availability, following the expected close by April 1, 2013 of approximately $290 million. 2013 EBITDAX is still expected to range between $475 million to $525 million. Post close of the BM sale, EPL's leverage is expected to be at 1.3x debt to projected 2013 EBITDAX using the midpoint of the guidance. (See the guidance section contained in this press release and the discussion of EBITDAX in the tables).  2013 Capital Budget and Current Operations  The Company currently plans to spend approximately $300 million on oil-dominated development and exploration activities in 2013. Development and infield exploration spending is budgeted primarily in the West Delta, East Bay, South Timbalier, and Ship Shoal core field areas. Capital spending is expected to be level throughout the year, intended to drive production growth and organic reserve replacement.The Company has continued its active drilling program from fourth quarter last year, with four rigs currently working within its core field areas. The Company plans to have up to 7 rigs running throughout the year, including barge, platform and jack-up rigs necessary to execute its capital program. In addition, the Company plans to spend approximately $30 million in 2013 on plugging and abandonment and other decommissioning activities.  Hedging Update  The Company has layered in additional downside protection in the form of swaps and collars for 2013 and 2014 to protect its cash flow. For full year 2013, EPL has a total of 11,157 Bbls of oil per day hedged, the majority of which is hedged using Brent swaps at a fixed price averaging $106.01 per Bbl. For full year 2013, EPL has a total of 9,562 Mcf per day of gas hedged, all of which is hedged using swaps at a fixed price averaging $3.51 per Bbl. For full year 2014, EPL has a total of 8,715 Bbls of oil per day hedged, all of which is hedged using Brent swaps at a fixed price averaging $101.13 per Bbl. For full year 2014, EPL has a total of 5,000 Mcf per day of gas hedged, all of which is hedged using swaps at a fixed price averaging $4.01 per Bbl.  First Quarter and Full Year 2013 Guidance  Note: This guidance is inclusive of the effects of the pending sale of the non-operated BM assets, expected to close April 1, 2013.  ESTIMATED PRODUCTION & SWAP HEDGE                                 VOLUMES                                                                  Net Production (per day)           1Q 2013             Full Year 2013 Oil, including NGLs (Bbls)         16,000  - 17,000  17,000  - 18,500 Natural gas (Mcf)                  27,000  - 33,000  24,000  - 30,000  Boe                              20,500  - 22,500  21,000  - 23,500 % Oil, including NGLs (using      77%                   80% midpoint of guidance)                                                                  Swap Contracted Volume                                            Oil (barrels)                      13,111                10,157 % of Oil swap contracted           82%      - 77%      60%      - 55% % of Boe swap contracted           64%      - 58%      48%      - 43% Average Swap Price Level           $105.13               $104.62                                                                  ESTIMATED EXPENSES (in Millions,                                  unless otherwise noted)                                                                  Lease Operating (including energy  $37.5  - $41.5  $150   - $160 insurance) General & Administrative (cash and $6.5   - $7.0   $26    - $28 non-cash) Taxes, other than on earnings (%   1%       - 3%       1%       - 3% of revenue) Exploration Expense                $2     - $4     $8     - $16 DD&A ($/Boe)                       $20.00 - $ 24.00 $20.00 - $24.00 Interest Expense (including amortizationof discount and       $13.0  - $14.0  $52    - $56 deferred financing costs)  ESTIMATED EBITDAX RANGE:  $475 Million to $525 Million (Midpoint: $500                                                         million)                                                                 ESTIMATED FREE CASH FLOW: $100 Million to $150 Million (Midpoint: $125                                                         million)  Conference Call Information  EPL has scheduled a conference call for today, March 7, 2013, at 9:00 A.M. Central Time/10:00 A.M. Eastern Time to review results for the fourth quarter and full year 2012 and to discuss its outlook for 2013.To participate in the EPL conference call, callers in the United States and Canada can dial (866) 845-8624 and international callers can dial (706) 634-0487. The Conference I.D. for callers is 16228946.  The call will be available for replay beginning two hours after the call is completed through midnight of March 21, 2013. For callers in the United States and Canada, the toll-free number for the replay is (855) 859-2056. For international callers the number is (404) 537-3406. The Conference I.D. for all callers to access the replay is 16228946.  The conference call will be webcast live as well as for on-demand listening at the Company's web site, www.eplweb.com. Listeners may access the call through the "Events and Webcasts" link in the Investor Relations section of the site.  Description of the Company  Founded in 1998, EPL is an independent oil and natural gas exploration and production company based in New Orleans, Louisiana, and Houston, Texas.The Company's operations are concentrated in the U.S. Gulf of Mexico shelf, focusing on the state and federal waters offshore Louisiana.For more information, please visit www.eplweb.com.  Forward-Looking Statements  This press release may contain forward-looking information and statements regarding EPL.Any statements included in this press release that address activities, events or developments that EPL "expects," "believes," "plans," "projects," "estimates" or "anticipates" will or may occur in the future are forward-looking statements.We believe these judgments are reasonable, but actual results may differ materially due to a variety of important factors.Among other items, such factors might include: hurricane and other weather-related interference with business operations; the failure of any closing conditions in the proposed sale of the non-operated Bay Marchand assets, which could terminate or significantly delay the transaction; the effects of delays in completion of, or shut-ins of, gas gathering systems, pipelines and processing facilities; stock market conditions; the trading price of EPL's common stock; cash demands caused by planned and unplanned capital expenditures; changes in general economic conditions; uncertainties in reserve and production estimates, particularly with respect to internal estimates that are not prepared by independent reserve engineers; unanticipated recovery or production problems; changes in legislative and regulatory requirements concerning safety and the environment as they relate to operations; oil and natural gas prices and competition; the impact of derivative positions; production expenses and expense estimates; cash flow and cash flow estimates; future financial performance; drilling and operating risks; our ability to replace oil and gas reserves; risks and liabilities associated with properties acquired in acquisitions; integration of acquired assets; volatility in the financial and credit markets or in oil and natural gas prices; and other matters that are discussed in EPL's filings with the Securities and Exchange Commission. (http://www.sec.gov/)  Appendix  PV-10 Definition and Discussion  PV-10 may be considered a non-GAAP financial measure as defined by the SEC. We believe that the presentation of PV-10 is relevant and useful to our investors as supplemental disclosure to the standardized measure, or after-tax amount, because it presents the discounted future net cash flows attributable to our proved reserves before taking into account future corporate income taxes and our current tax structure. Because the standardized measure is dependent on the unique tax situation of each company, our calculation may not be comparable to those of our competitors. Because of this, PV-10 can be used within the industry and by creditors and securities analysts to evaluate estimated net cash flows from proved reserves on a more comparable basis.                                                                                                                   EPL OIL & GAS, INC. CONSOLIDATED STATEMENTS OF OPERATIONS (In thousands) (Unaudited)                                                                             Three Months Ended        Year Ended                      December 31,              December 31,                     2012         2011         2012        2011 Revenues:                                                Oil and natural gas  $137,863   $103,341   $422,529  $348,207 Other                1,036       23          1,104      120                     138,899     103,364     423,633    348,327                                                         Costs and expenses:                                      Lease operating      32,783      17,776      94,850     70,281 Transportation       205         289         615        779 Exploration expenditures and dry 937         11,925      18,799     14,268 hole costs Impairments          2,677       13,269      8,883      32,466 Depreciation, depletion and        34,649      31,543      113,581    104,624 amortization Accretion of liability for asset  5,534       3,770       15,565     15,942 retirement obligations General and          6,215       4,197       23,208     18,741 administrative Taxes, other than on 3,173       3,859       13,007     14,365 earnings Other                62          3,595       4,678      9,735 Total costs and      86,235      90,223      293,186    281,201 expenses                                                         Income from          52,664      13,141      130,447    67,126 operations                                                         Other income                                             (expense): Interest income      8           38          136        102 Interest expense     (13,487)    (5,068)     (28,568)   (17,548) Loss on derivative   (1,440)     (20,747)    (13,305)   (5,870) instruments Loss on early extinguishment of    -           -           -          (2,377) debt                     (14,919)    (25,777)    (41,737)   (25,693)                                                         Income (loss) before 37,745      (12,636)    88,710     41,433 income taxes Deferred income tax  (13,592)    5,295       (29,900)   (14,822) benefit (expense)                                                         Net income (loss)    $24,153    $(7,341)   $58,810   $26,611                                                         Net income (loss),   $24,153    $(7,341)   $58,810   $26,611 as reported Add back:                                                Unrealized loss (gain) due to the change in fair       1,439       19,647      9,491      (11,475) market value of derivative contracts Impairments          2,677       13,269      8,883      32,466 Loss on early extinguishment of    -           -           -          2,377 debt Loss (gain) on abandonment          (957)       2,373       2,448      6,984 activities Deduct:                                                  Income tax adjustment for above (1,150)     (12,986)    (7,579)    (11,321) items                                                         Adjusted Non-GAAP    $26,162    $14,962    $72,053   $45,642 net income                                                         EBITDAX                                                  Reconciliation:                                                         Net income (loss),   $24,153    $(7,341)   $58,810   $26,611 as reported Add back:                                                Income taxes         13,592      (5,295)     29,900     14,822 Net interest expense 13,479      5,030       28,432     17,446 Depreciation, depletion,           40,183      35,313      129,146    120,566 amortization and accretion Impairments          2,677       13,269      8,883      32,466 Loss on extinguishment of    -           -           -          2,377 debt Exploration expenditures and dry 937         11,925      18,799     14,268 hole costs Loss (gain) on abandonment          (957)       2,373       2,448      6,984 activities Less impact of:                                          Unrealized (gain) loss due to the change in fair       1,439       19,647      9,491      (11,475) market value of derivative contracts                                                         EBITDAX              $95,503    $74,921    $285,909  $224,065                                                         Weighted average dilutive common      38,998      39,508      39,034     40,050 shares outstanding                                                                           EBITDAX is defined as net income (loss) before income taxes, net interest expense, depreciation, depletion, amortization and accretion, impairments, loss on extinguishment of debt, exploration expenditures and dry hole costs, loss (gain) on abandonment activities and cumulative effect of change in accounting principle, and further deducts the unrealized gain or loss on our derivative contracts. We have reported EBITDAX because we believe EBITDAX is a measure commonly reported and widely used in our industry as an indicator of a company's ability to internally fund exploration and development activities and incur and service debt.EBITDAX is not a calculation        based on generally accepted accounting principles (GAAP) in the United States and should not be considered in isolation from or as a substitute for net income, as an indication of operating performance or cash flows from operating activities or as a measure of liquidity.Investors should carefully consider the specific items included in our computation of EBITDAX.Investors should be cautioned that EBITDAX as reported by us may not be comparable in all instances to EBITDAX as reported by other companies.In addition, EBITDAX does not represent funds available for discretionary use.                                                                                                                                   EPL OIL & GAS, INC. CONSOLIDATED STATEMENTS OF NET CASH PROVIDED BY OPERATING ACTIVITIES (In thousands) (Unaudited)                                                                                                                                                        Three Months Ended         Year Ended                           December 31,               December 31,                          2012           2011        2012         2011 Cash flows from operating                                       activities: Net income (loss)         $24,153      (7,341)    58,810      26,611 Adjustments to reconcile net income (loss) to net cash provided by operating                         activities: Depreciation, depletion   34,649        31,543     113,581     104,624 and amortization Accretion of liability for asset retirement      5,534         3,770      15,565      15,942 obligations Unrealized loss (gain) on 1,439         19,647     9,491       (11,475) derivative contracts Non-cash compensation     1,224         676        4,717       2,509 Deferred income taxes     13,766        (5,295)    29,900      14,822 Exploration expenditures  130           11,092     4,227       11,239 Impairments               2,677         13,269     8,883       32,466 Amortization of deferred financing costs and       1,040         505        2,556       1,657 discount on debt Loss on early             -            -         -          2,377 extinguishment of debt Other                     (957)         2,373      2,448       6,984 Changes in operating                                            assets and liabilities: Trade accounts receivable (38,718)      (3,607)    (33,547)    (10,037) Other receivables         -            805        -          2,088 Prepaid expenses          (3,015)       (2,416)    1,047       (7,623) Other assets              (217)         (353)      145         (1,215) Accounts payable and      17,328        7,087      31,477      12,650 accrued expenses Other liabilities         (7,782)       (6,438)    (35,429)    (32,367)                                                                Net cash provided by      $51,251      65,317     213,871     171,252 operating activities                                                                Reconciliation of                                               discretionary cash flow: Net cash provided by      51,251        65,317     213,871     171,252 operating activities Changes in working        32,404        4,922      36,307      36,504 capital Non-cash exploration expenditures and          (2,807)       (24,361)   (13,110)    (43,705) impairments Total exploration expenditures, dry hole    3,614         25,194     27,682      46,734 costs and impairments Discretionary cash flow   $84,462      $71,072   $264,750   $210,785                                                                                                                               The table above reconciles discretionary cash flow to net cash provided by or used in operating activities. Discretionary cash flow is defined as cash flow from operations before changes in working capital and exploration expenditures. Discretionary cash flow is widely accepted as a financial indicator of an oil and natural gas company's ability to generate cash which is used to internally fund exploration and development activities, pay dividends and service debt. Discretionary cash flow is presented based on management's belief that this non-GAAP financial measure is useful information to investors because it is widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies within the oil and natural gas exploration and production industry. Many investors use the published research of these analysts in making their investment decisions. Discretionary cash flow is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating activities, as defined by GAAP, or as a measure of liquidity, or an alternative to net income. Investors should be cautioned that discretionary cash flow as reported by the Company may not be comparable in all instances to discretionary cash flow as reported by other companies.                                                                                                                                  EPL OIL & GAS, INC. SELECTED PRODUCTION, PRICING AND OPERATIONAL STATISTICS (Unaudited)                                                                                            Three Months Ended         Year Ended                             December 31,              December31,                            2012           2011        2012        2011                                                                 PRODUCTION AND PRICING                                           Net Production (per day):                                        Crude Oil (Bbls)            13,057        9,041      9,963      7,796 Natural gas liquids (Bbls)  459           399        435        293 Oil (Bbls)                  13,516        9,440      10,398     8,089 Natural gas (Mcf)           28,198        15,239     17,852     17,968 Total (Boe)                 18,216        11,980     13,373     11,084 Average Sales Prices:                                            Crude Oil (Bbls)            $106.07      116.40     108.88     110.82 Natural gas liquids (Bbls)  38.21         55.68      41.93      55.40 Oil (Bbls)                  103.77        113.84     106.08     108.81 Natural gas (per Mcf)       3.40          3.19       2.89       4.11 Average (per Boe)           82.27         93.76      86.33      86.07 Oil and Natural Gas                                              Revenues (in thousands): Crude Oil                   $127,422     96,823     396,989    315,347 Natural gas liquids        1,613         2,043      6,674      5,928 Oil                        129,035       98,866     403,663    321,275 Natural gas                 8,828         4,476      18,866     26,932 Total                      137,863       103,342    422,529    348,207                                                                 Impact of derivatives settled during the period                                        (1): Oil (per Bbl)               $0.37        (1.27)     (0.88)     (5.87) Natural gas (per Mcf)       (0.18)        --        (0.07)     --                                                                 OPERATIONAL STATISTICS                                           Average Costs (per Boe):                                         Lease operating expense     $19.56       16.13      19.38      17.37 Depreciation, depletion and 20.68         28.62      23.21      25.86 amortization Accretion expense           3.30          3.42       3.18       3.94 Taxes, other than on        1.89          3.50       2.66       3.55 earnings General and administrative  3.71          3.81       4.74       4.63                                                                 (1) The derivative amounts represent the realized portion of gains or losses on derivative contracts settled during the period which are included in Other income (expense) in the consolidated statements of operations.                                                                                                                                        EPL OIL & GAS, INC. CONSOLIDATED BALANCE SHEETS (In thousands, except share data)                                                                                                                          December 31,                                                       2012         2011                                                                    ASSETS                                                              Current assets:                                                     Cash and cash equivalents                              $1,521     $80,128 Trade accounts receivable - net                        67,991      31,817 Fair value of commodity derivative instruments         3,302       587 Deferred tax asset                                     3,322       - Prepaid expenses                                       9,873       11,046 Total current assets                                   86,009      123,578                                                                    Property and equipment                                 2,025,647   1,082,248 Less accumulated depreciation, depletion and           (427,580)   (305,110) amortization Net property and equipment                             1,598,067   777,138                                                                    Restricted cash                                        6,023       6,023 Fair value of commodity derivative instruments         211         - Deferred financing costs --- net of accumulated        12,386      5,452 amortization Other assets                                           2,931       3,029                                                       $1,705,627 $915,220                                                                    LIABILITIES AND STOCKHOLDERS' EQUITY                                Current liabilities:                                                Accounts payable                                       $34,772    $25,393 Accrued expenses                                       117,372     58,538 Asset retirement obligations                           30,179      25,578 Fair value of commodity derivative instruments         10,026      1,056 Deferred tax liabilities                               -           2,823 Total current liabilities                              192,349     113,388                                                                    Long-term debt                                         689,911     204,390 Asset retirement obligations                           204,931     73,769 Deferred tax liabilities                               67,694      31,775 Fair value of commodity derivative instruments         3,637       190 Other                                                  1,132       663                                                       1,159,654   424,175                                                                    Commitments and contingencies                                                                                                         Stockholders' equity:                                               Preferred stock, $0.001 par value per share. Authorized 1,000,000 shares; no shares issued and      -           - outstanding at December 31, 2012 and 2011 Common stock, $0.001 par value per share. Authorized 75,000,000 shares; shares issued 40,601,887 and 40,326,451 at December 31, 2012 and 2011,              40          40 respectively; shares outstanding 39,103,203 and 39,404,106 at December 31, 2012 and 2011, respectively Additional paid-in capital                             510,469     505,235 Treasury stock, at cost, 1,498,684 and 922,345 shares  (20,477)    (11,361) at December 31, 2012 and 2011, respectively Retained earnings (accumulated deficit)                55,941      (2,869) Total stockholders' equity                             545,973     491,045                                                       $1,705,627 $915,220  EPL OIL & GAS, INC. SUPPLEMENTAL OIL & GAS DISCLOSURE (Unaudited)                                                                                                                                                                                                                  Oil            Natural Gas      Equivalents                              (Mbbl)         (Mmcf)           (Mboe) Proved developed and                                         undeveloped reserves:                                                             December 31, 2010             17,223        61,251          27,431                                                             Acquisitions                  7,987         8,640           9,427 Extensions, discoveries and   2,266         4,664           3,043 other additions Revisions                     2,778         (6,678)         1,666 Production                    (2,953)       (9,092)         (4,468) December 31, 2011             27,301        58,785          37,099                                                             Acquisitions                  16,430        115,876         35,742 Extensions, discoveries and   6,388         10,241          8,095 other additions Revisions                     1,128         4,033           1,800 Production                    (3,805)       (8,996)         (5,304) December 31, 2012             47,442        179,939         77,432                                                                                                                         Proved developed reserves:                                                                                               December 31, 2010             15,974        56,410          25,376 December 31, 2011             24,791        52,739          33,581 December 31, 2012             37,908        120,687         58,022                                                             Costs incurred for oil and natural gas property acquisition, exploration and development activities for the two-years ended December 31 are as follows (in thousands):                                                                                          2012           2011                                                                          Acquisitions:                                                Proved                        706,322       261,812          Unproved                      7,496         14               Exploration                   43,338        17,129           Development                   179,728       83,420           Total finding and development 223,066       100,549          costs Total finding, development    936,884       362,375          and acquisition costs Asset retirement liabilities  1,210         157              incurred Total cost incurred           $938,094      $362,532          CONTACT:  Investors/Media            T.J. Thom, Chief Financial Officer           504-799-1902           tthom@eplweb.com  EPL Oil & Gas, Inc. Logo