UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(Mark One)

x     QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For  the quarterly period ended June 30, 2013 

OR

¨     TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number: 001-16179

 

EPL Oil & Gas, Inc.

(Exact name of registrant as specified in its charter)

 

 

(713) 228-0711 

(Registrant’s telephone number, including area code)

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No   ¨ 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No  ¨ 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No   x 

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.    Yes  x    No  ¨ 

As of July 26, 2013, there were 39,047,405 shares of the registrant’s Common Stock, par value $0.001 per share, outstanding.

 

 

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TABLE OF CONTENTS

 

 

 

 

 

 

 

 

 

 

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PART I—FINANCIAL INFORMATION

Item 1.            FINANCIAL STATEMENTS.

EPL OIL & GAS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

(In thousands, except share data)

 

See accompanying notes to condensed consolidated financial statements. 

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EPL OIL & GAS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)

(In thousands, except per share data)

 

 

 

See accompanying notes to condensed consolidated financial statements.

 

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EPL OIL & GAS, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

(In thousands)

 

 

See accompanying notes to condensed consolidated financial statements.             

 

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EPL OIL & GAS, INC. AND SUBSIDIARIES  

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

(1) Basis of Presentation

EPL Oil & Gas, Inc. (“we,” “our,” “us,” or “the Company”) was incorporated as a Delaware corporation on January 29, 1998. We are an independent oil and natural gas exploration and production company. Our current operations are concentrated in the U.S. Gulf of Mexico shelf focusing on state and federal waters offshore Louisiana.

The financial information as of June 30, 2013 and for the three- and six-month periods ended June 30, 2013 and June 30, 2012 has not been audited. However, in the opinion of management, all adjustments (which include only normal, recurring adjustments) necessary to present fairly the financial position and results of operations for the periods presented have been included therein. Certain information and footnote disclosures normally in financial statements prepared in accordance with generally accepted accounting principles have been condensed or omitted pursuant to rules and regulations of the Securities and Exchange Commission. The condensed consolidated balance sheet at December 31, 2012 has been derived from the audited financial statements at that date. These financial statements and footnotes should be read in conjunction with the financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2012 (the “2012 Annual Report”). The results of operations and cash flows for the first six months of the year are not necessarily indicative of the results of operations which might be expected for the entire year.

(2) Acquisitions and Dispositions

Sale of Non-Operated Bay Marchand Asset

On April 2, 2013, we sold certain shallow water Gulf of Mexico shelf oil and natural gas interests located within the non-operated Bay Marchand field (the “BM Interests”) to the property operator for $51.5 million in cash and the buyer’s assumption of liabilities recorded on our balance sheet of $11.3 million resulting in total consideration of $62.8 million, subject to customary adjustments to reflect the January 1, 2013 economic effective date.  We recognized a pre-tax gain of $26.4 million in the three months ended June 30, 2013.  The following table summarizes the carrying amount of the net assets sold and reflects management’s estimates of customary adjustments to the sale price of approximately $1.1 million to reflect the economic effective date of January 1, 2013.

   

The cash proceeds from this sale of assets are on deposit with a qualified intermediary in contemplation of a potential tax-deferred exchange of properties.  However, there can be no assurance that we will successfully execute such an exchange. The funds will remain on deposit with the qualified intermediary until used in exchange for replacement properties or until the expiration date of the underlying escrow agreement, which is September 29, 2013. The deposit is reflected as Restricted cash in the current assets section of our condensed consolidated balance sheet at June 30, 2013. 

 The Hilcorp Acquisition

On October 31, 2012,  we acquired from Hilcorp Energy GOM Holdings, LLC (“Hilcorp”) 100% of the membership interests of Hilcorp Energy GOM, LLC (the “Hilcorp Acquisition”), which owned certain shallow water Gulf of Mexico shelf oil and natural gas interests (the “Hilcorp Properties”), for $550 million in cash, subject to customary adjustments to reflect an economic effective date of July 1, 2012.  As of December 31, 2012, the Hilcorp Properties had estimated proved reserves of approximately 37.2 Mmboe, of which 49% were oil and 58% were proved developed reserves.  The primary factors considered by management in acquiring the Hilcorp Properties include the belief that the Hilcorp Acquisition provides an opportunity to significantly increase our reserves, production volumes and drilling portfolio, while maintaining our focus on oil-weighted assets in our core area of expertise on the Gulf of Mexico shelf.  The Hilcorp Acquisition also provides us with access to infrastructure and extensive acreage, with significant exploitation and development potential.

The Hilcorp Acquisition was financed with cash on hand, the net proceeds from the sale of $300.0 million in aggregate principal amount of 8.25% senior notes due 2018 (“the 2012 Senior Notes”) and borrowings under our expanded senior credit facility.  See Note 5, “Indebtedness,” for more information regarding our 2012 Senior Notes.

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The following allocation of the purchase price is preliminary and includes estimates.  This preliminary allocation is based on information that was available to management at the time these condensed consolidated financial statements were prepared and takes into account current market conditions and estimated market prices for oil and natural gas.  Management has not yet had the opportunity to complete its assessment of fair values of the assets acquired and liabilities assumed.  In addition, the purchase price could change materially as management finalizes adjustments to purchase price provided for by the purchase and sale agreement.  Accordingly, the allocation may change materially as additional information becomes available and is assessed by management.

The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments to purchase price provided for by the purchase and sale agreement of approximately $6.2 million to reflect an economic effective date of July 1, 2012.  

 

The South Timbalier Acquisition

On May 15, 2012, we acquired from W&T Offshore, Inc. (“W&T”) an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests in our South Timbalier 41 field (the “ST41 Interests”) located in the Gulf of Mexico for $32.4 million in cash, subject to customary adjustments to reflect an economic effective date of April 1, 2012 (the “ST41 Acquisition”). We estimate that the proved reserves as of the April 1, 2012 economic effective date totaled approximately 1.0 Mmboe, of which 51% were oil and 84% were proved developed reserves. Prior to the ST41 Acquisition, we owned a 60% working interest in these properties, and W&T owned a 40% working interest. As a result of the ST41 Acquisition, we became the sole working interest owner of the South Timbalier 41 field. We funded the ST41 Acquisition with cash on hand.

The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $0.4 million to reflect an economic effective date of April 1, 2012.  

We have accounted for our acquisitions using the purchase method of accounting for business combinations, and therefore we have estimated the fair value of the assets acquired and the liabilities assumed as of their respective acquisition dates. In the estimation of fair value, management uses various valuation methods including (i) comparable company analysis, which estimates the value of the acquired properties based on the implied valuations of other similar operations; (ii) comparable asset transaction analysis, which estimates the value of the acquired operations based upon publicly announced transactions of assets with similar characteristics; (iii) comparable merger transaction analysis, which, much like comparable asset transaction analysis, estimates the value of operations based upon publicly announced transactions with similar characteristics, except that merger analysis analyzes public to public merger transactions rather than solely asset transactions; and (iv) discounted cash flow analysis. The fair value is based on subjective estimates and assumptions, which are inherently subject to significant uncertainties which are beyond our control. These assumptions represent Level 3 inputs, as further discussed in Note 7, “Fair Value Measurements.”

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Results of Operations and Pro Forma Information

The following table sets forth revenues and lease operating expenses attributable to the Hilcorp Properties and the ST41 Interests. 

We have determined that the presentation of net income attributable to the Hilcorp Properties and the ST41 Interests is impracticable due to the integration of the related operations upon acquisition.

The following supplemental pro forma information presents consolidated results of operations as if the Hilcorp Acquisition and the ST41 Acquisition had occurred on January 1, 2011. The supplemental unaudited pro forma information was derived from a) our historical consolidated statements of operations, b) the statements of operations of Hilcorp Energy GOM, LLC and c) the statements of revenues and direct operating expenses for the ST41 Interests, which were derived from our historical accounting records. This information does not purport to be indicative of results of operations that would have occurred had the acquisitions occurred on January 1, 2011, nor is such information indicative of any expected future results of operations.

 

 

 

 

 (3) Earnings per Share

The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.

 

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The following table indicates the number of shares underlying outstanding stock-based awards excluded from the computation of dilutive weighted average shares because their effect was antidilutive for the periods indicated.

 

 

 

 

 

 

 

(4) Asset Retirement Obligations

The following table reconciles the beginning and ending aggregate recorded amount of our asset retirement obligations. 

 

 

 

 

(5) Indebtedness

The following table sets forth our indebtedness.

8.25% Senior Notes

The 8.25% senior notes consist of $510.0 million in aggregate principal amount of our 8.25% senior notes due 2018 (the “8.25% Senior Notes”) issued under an Indenture dated February 14, 2011 (the “2011 Indenture”). The 8.25% Senior Notes bear interest from the date of their issuance at an annual rate of 8.25% with interest due semi-annually, in arrears, on February 15th and August 15th of each year. The 8.25% Senior Notes are fully and unconditionally guaranteed, jointly and severally, on an unsecured senior basis initially by each of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries). The 8.25% Senior Notes will mature on February 15, 2018.  The effective interest rate on the 8.25% Senior Notes is approximately 9.1%.

We issued the 8.25% Senior Notes in two different private placements, as follows. On February 14, 2011, we issued $210.0 million in aggregate principal amount of our 8.25% senior notes due 2018 (the “2011 Senior Notes”) under an Indenture dated as of February 14, 2011 (the “2011 Indenture”). We used the net proceeds from the offering of the 2011 Senior Notes of $202.0 million, after deducting the initial purchasers’ discount and offering expenses payable by us, to acquire an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests surrounding the Mississippi River delta and a related gathering system from Anglo-Suisse Offshore Partners, LLC (“ASOP”) for a purchase price of $200.7 million, before adjustments to reflect an economic effective date of January 1, 2011 (the “ASOP

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Acquisition”).  For additional information regarding the 2011 Senior Notes, see Note 7, “Indebtedness,” of our 2012 Annual Report.

On October 25, 2012, we issued $300.0 million in aggregate principal amount of our 2012 Senior Notes under an Indenture dated as of October 25, 2012 (the “2012 Indenture”).  As described in Note 2, “Acquisitions,” we used the net proceeds from the offering of the 2012 Senior Notes of $289.5 million, after deducting the initial purchasers’ discount, to fund a portion of the Hilcorp Acquisition.  The purchase price of the 2012 Senior Notes included $4.8 million of accrued interest for the period from August 15, 2012 to October 25, 2012, which we recorded as interest payable.

The 2012 Senior Notes were offered in a private placement only to qualified institutional buyers under Rule 144A promulgated under the Securities Act of 1933, as amended (the “Securities Act”), or to persons outside of the United States in compliance with Regulation S promulgated under the Securities Act. The 2012 Senior Notes had terms that were substantially identical to the terms of our 2011 Senior Notes.  Pursuant to a registration rights agreement executed as part of the sale of the 2012 Senior Notes (the “Registration Rights Agreement”), we have issued publicly registered additional notes under our 2011 Indenture in exchange for the 2012 Senior Notes. As a result of this exchange offer, 100% in aggregate principal amount of the 2012 Senior Notes was exchanged for the notes under the 2011 Indenture, effective as of June 10, 2013.  All of the 8.25% Senior Notes are now issued under the 2011 Indenture, regardless of which private placement they were issued under.  For more information regarding the 2012 Senior Notes, see Note 7, “Indebtedness,” of our 2012 Annual Report.

Senior Credit Facility

On February 14, 2011, we entered into our senior secured credit facility with BMO Capital Markets, as lead arranger, and Bank of Montreal, as administrative agent and a lender, and the other lender parties thereto (as amended and restated, the “Senior Credit Facility”). The original terms of our Senior Credit Facility established a revolving credit facility with a four-year term that could be used for revolving credit loans and letters of credit up to an aggregate principal amount of $250.0 million. On October 31, 2012, in connection with the Hilcorp Acquisition, through an amendment and restatement of our Senior Credit Facility, the aggregate commitment under this facility was increased to a maximum of $750.0 million and the maturity date was extended to October 31, 2016. The maximum amount of letters of credit that may be outstanding at any one time is $20.0 million. The amount available under the revolving credit facility is limited by the borrowing base. The borrowing base under our Senior Credit Facility has been determined at the discretion of the lenders, based on the collateral value of our proved reserves and is subject to potential special and regular semi-annual redeterminations.  On October 31, 2012, the borrowing base was increased from $200.0 million to $425.0 million. We recently completed our semi-annual redetermination and our borrowing base remains at $425.0 million. In addition, in July 2013, our Senior Credit Facility was amended to increase the limit applicable to certain restricted payments permitted by the agreement.  As of June 30, 2013 and December 31, 2012, we had outstanding under the Senior Credit Facility  $165.0 million and $195.0 million, respectively.  For additional information regarding our Senior Credit Facility, see Note 7, “Indebtedness,” of our 2012 Annual Report.

(6) Derivative Instruments and Hedging Activities

We enter into derivative transactions to reduce exposure to fluctuations in the price of oil and natural gas for a portion of our production. Our fixed-price swaps fix the sales price for a limited amount of our production and, for the contracted volumes, eliminate our ability to benefit from increases in the sales price of the production. Our collars limit our exposure to declines in the sales price of oil while giving us the ability to benefit from increases to a certain level in the sales price of oil for a limited amount of our production. Derivative instruments are carried at their fair value on the condensed consolidated balance sheets as Fair value of commodity derivative instruments, and all unrealized and realized gains and losses are recorded in Gain (loss) on derivative instruments in Other income (expense) in the condensed consolidated statements of operations. See Note 7 for information regarding fair values of our derivative instruments.

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The following table sets forth our derivative instruments outstanding as of June 30, 2013.

Oil Contracts

 

 

 

 

 

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Gas Contracts

 

 

The following table presents information about the components of our gain on derivative instruments.

 

 

 

 

 

(7) Fair Value Measurements

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting Standards Codification (“ASC”) Topic 820, “Fair Value Measurements and Disclosures,” establishes a fair value hierarchy with three levels based on the reliability of the inputs used to determine fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets and liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions.

As of June 30, 2013 and December 31, 2012, we held certain financial assets and liabilities that are required to be measured at fair value on a recurring basis, primarily our commodity derivative instruments. The fair values of our derivative instruments were measured according to the market approach or, if necessary, the income approach using price inputs published by NYMEX and IntercontinentalExchange, Inc., or ICE. These price inputs include settled exchange prices and quoted prices for assets and liabilities similar to those held by us and meet the definition of Level 2 inputs within the fair value hierarchy.

In December 2011, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities” (“ASU 2011-11”). ASU 2011-11 requires disclosure of information about offsetting and related arrangements to enable users of financial statements to understand the effect or potential effect of netting arrangements on an entity’s financial position, including the effect or potential effect of rights of setoff associated with certain financial instruments and derivative instruments. In January 2013, the FASB issued ASU No. 2013-01, “Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities,” to clarify that ASU 2011-11 applies to derivatives, repurchase agreements and securities lending transactions.  Our commodity derivative instruments are subject to the terms of agreements with each of our counterparties that provide for the liquidation and settlement of all transactions with that counterparty in the event of default or termination.  Our counterparties under these agreements are participants in our Senior Credit Facility.  Although our derivative instruments are subject to such enforceable set-off arrangements, we do not elect to offset amounts reported in our condensed consolidated balance sheet.

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The following table presents the fair values of our commodity derivative instruments at their gross amounts and reflects the impact of our set-off arrangements which qualify for net presentation.

 

The carrying values reported in the condensed consolidated balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximate fair value due to the short term maturities of these instruments.  The fair value of the 8.25% Senior Notes is based on quoted prices, which are Level 1 inputs within the fair value hierarchy.  The carrying value of the Senior Credit Facility approximates its fair value because the interest rates are variable and reflective of market rates, which are Level 2 inputs within the fair value hierarchy.

The following table sets forth the carrying values and estimated fair values of our long-term indebtedness.

 

Effective June 1, 2013, we entered into agreements with a group of capital market participants (the “Counterparties”) whereby if a named wind storm occurs in a specified area of the Gulf of Mexico and that storm meets certain strength criteria and one or more scheduled assets within that specified area are deemed totally destroyed, then the Counterparties will pay to us a fixed amount of cash proceeds specific for each such destroyed asset. These agreements are financial instruments and are considered weather derivatives under the applicable authoritative guidance related to financial instruments. We recognized the premiums paid as current assets, which we are amortizing to expense over the terms of the agreements. At June 30, 2013, we estimate that the fair value of these financial instruments approximates the carrying amount of approximately $6.7 million, based on the amount of premiums paid, which is a Level 3 input within the fair value hierarchy.

We evaluate our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicate that the carrying values may not be recoverable. Our assessment of possible impairment of proved oil and natural gas properties is based on our best estimate of future prices, costs and expected net future cash flows by property (generally analogous to a field or lease). An impairment loss is indicated if undiscounted net future cash flows are less than the carrying value of a property. The impairment expense is measured as the shortfall between the net book value of the property and its estimated fair value, which is measured based on the discounted net future cash flows from the property. The inputs used to estimate the fair value of our oil and natural gas properties are based on our estimates of future events, including projections of future oil and natural gas sales prices, amounts of recoverable oil and natural gas reserves, timing of future production, future costs to develop and produce our oil and natural gas and discount factors. These inputs meet the definition of Level 3 inputs within the fair value hierarchy.  Impairments for the three and six months ended June 30, 2013 were primarily related to reservoir performance at a gas well in one of our smaller producing fields. This field was determined to have future net cash flows less than its carrying value resulting in the write down of this property to its estimated fair value at June 30, 2013.  Impairments for the three and six months ended June 30, 2012 were primarily due to the decline in our estimate of future natural gas prices affecting certain of our natural gas producing fields and to reservoir performance of one of our natural gas producing fields.

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As addressed in Note 2, “Acquisitions and Dispositions,” we apply fair value concepts in estimating and allocating the fair value of assets acquired and liabilities assumed in acquisitions in accordance with purchase accounting for business combinations. The inputs to the estimated fair values of assets acquired and liabilities assumed are described in Note 2.

 (8) Commitments and Contingencies

On March 20, 2013, we were the high bidder on five leases at the Central Gulf of Mexico Lease Sale 227. The five high bid lease blocks cover a total of 13,892 acres on a gross and net basis and are all located in the shallow Gulf of Mexico within our core area of operations. Our share of the high bids totaled approximately $2.1 million. As of June 30, 2013, we had been awarded four (4) of the leases totaling $1.8 million, of which $1.5 million was paid in July 2013. In July, we were awarded the final lease for $0.3 million, which amount is due in August.

We maintain restricted escrow funds in a trust for future abandonment costs at our East Bay field. The trust was originally funded over time with $15 million and, with accumulated interest, increased to $16.7 million at December 31, 2008. We may draw from the trust upon completion of qualifying abandonment activities at our East Bay field. At June 30, 2013, we had $6.0 million remaining in restricted escrow funds for decommissioning work in our East Bay field, which will remain restricted until substantially all required decommissioning in the East Bay field is complete. Amounts on deposit in the trust account are reflected in Restricted cash on our condensed consolidated balance sheets.

We record liabilities when we deliver production that is in excess of our interest in certain properties. In addition to these imbalances, we may, from time to time, be allocated cash sales proceeds in excess of amounts that we estimate are due to us for our interest in production. These allocations may be subject to further review, may require more information to resolve or may be in dispute. In July 2010, we were notified by a purchaser of oil production from one of our non-operated fields that we were allocated, and received sales proceeds from, more oil production than we actually sold to that purchaser. These third party misallocations may have dated back to 2006. The oil purchaser’s initial estimate of the oil volumes misallocated to us was approximately 74,000 barrels, which may have been valued at up to $6.9 million based on information provided by the oil purchaser. We had previously recorded as a liability an amount that we believed may have been payable related to a potential reallocation, which amount was reflected in the accompanying condensed consolidated balance sheets in Accrued expenses as of December 31, 2012.   As part of the consideration for its purchase of the BM Interests, the buyer assumed any amounts due related to this matter, as a result of which we have removed the liability from our balance sheet.  See Note 2, “Acquisitions and Dispositions-Sale of Non-Operated Bay Marchand Asset” for more information.

We and our oil and gas joint interest owners are subject to periodic audits of the joint interest accounts for leases in which we participate and/or operate. As a result of these joint interest audits, amounts payable or receivable by us for costs incurred or revenue distributed by the operator or by us on a lease may be adjusted, resulting in adjustments, increases or decreases, to our net costs or revenues and the related cash flows. Such adjustments may be material. When they occur, these adjustments are recorded in the current period, which generally is one or more years after the related cost or revenue was incurred or recognized by the joint account.

In the ordinary course of business, we are a defendant in various other legal proceedings. We do not expect our exposure in these other proceedings, individually or in the aggregate, to have a material adverse effect on our financial position, results of operations or liquidity.

(9) Supplemental Condensed Consolidating Financial Information

In connection with issuing the 8.25% Senior Notes described in Note 5, all of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries) (the “Guarantor Subsidiaries”) jointly and severally guaranteed the payment obligations under our 8.25% Senior Notes.  The guarantees are full and unconditional, as those terms are used in Rule 3-10 of Regulation S-X, except that a Guarantor Subsidiary can be automatically released and relieved of its obligations under certain customary circumstances contained in the indenture governing the 8.25% Senior Notes.  So long as other applicable provisions of the indenture are adhered to, these customary circumstances include: when a Guarantor Subsidiary is declared “unrestricted” for covenant purposes, when the requirements for legal defeasance or covenant defeasance or to discharge the indenture have been satisfied, or when the Guarantor Subsidiary is sold or sells all of its assets. The following supplemental financial information sets forth, on a consolidating basis, the balance sheets, statements of operations and cash flow information for EPL Oil & Gas, Inc. (Parent Company Only) and for the Guarantor Subsidiaries. We have not presented separate financial statements and other disclosures concerning the Guarantor Subsidiaries, or for any individual Guarantor Subsidiary, because management has determined that such information is not material to investors.

The supplemental condensed consolidating financial information has been prepared pursuant to the rules and regulations for condensed financial information and does not include all disclosures included in annual financial statements. Certain reclassifications were made to conform all of the financial information to the financial presentation on a consolidated basis. The principal eliminating entries eliminate investments in subsidiaries, intercompany balances and intercompany revenues and expenses.

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Supplemental Condensed Consolidating Balance Sheet

As of June 30, 2013