##### Table of Contents





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, 2010

OR



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

Commission file number: 001-16179





ENERGY
PARTNERS, LTD.

(Exact Name of Registrant as Specified in Its Charter)







|                                                               |  |                                        
|-------------------------------------------------------------- |  | ---------------------------------------
|Delaware                                                       |  | 72-1409562                             
|(State or Other Jurisdiction of
Incorporation or Organization) |  | (I.R.S. Employer
Identification Number)
|                                                               | 
|201 St. Charles Ave., Suite 3400 New Orleans, Louisiana        |  | 70170                                  
|(Address of principal executive offices)                       |  | (Zip code)                             

(504) 569-1875

(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   ̈    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.



|                        |  |                                                   |  |                           |  |  
|----------------------- |  | ------------------------------------------------- |  | ------------------------- |  | -
|Large accelerated filer |  |  ̈                                                 |  | Accelerated filer         |  |  ̈
|                        |  |                                                   | 
|Non-accelerated filer   |  |  ̈  (Do not check if a smaller reporting company). |  | Smaller reporting company |  | x

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 August 2, 2010, there were 40,090,810 shares of the Registrants Common Stock, par value $0.001 per share, outstanding.









---

##### Table of Contents

TABLE OF CONTENTS



|                                                                                                                       |  |                                                                                       |  |     
|---------------------------------------------------------------------------------------------------------------------- |  | ------------------------------------------------------------------------------------- |  | ----
|                                                                                                                       |  |                                                                                       |  | Page
|                                                                                                                       | 
|PART I - FINANCIAL INFORMATION                                                                                         |  |                                                                                      
|                                                                                                                       |  |                                                                                      
|Item 1.                                                                                                                |  | Financial Statements:                                                                 |  | 3   
|                                                                                                                       | 
|Condensed Consolidated Balance Sheets (Unaudited) as of June 30, 2010 and December 
31, 2009                           |  | 3                                                                                    
|                                                                                                                       | 
|Condensed Consolidated Statements of Operations (Unaudited) for the three and six months ended June 30,
 2010 and 2009 |  | 4                                                                                    
|                                                                                                                       | 
|Condensed Consolidated Statements of Cash Flows (Unaudited) for the six months ended June 
30, 2010 and 2009           |  | 5                                                                                    
|                                                                                                                       | 
|Notes to Condensed Consolidated Financial Statements (Unaudited)                                                       |  | 6                                                                                    
|                                                                                                                       |  |                                                                                      
|Item 2.                                                                                                                |  | Managements Discussion and Analysis of Financial Condition and Results of
Operations |  | 10  
|                                                                                                                       |  |                                                                                      
|Item 3.                                                                                                                |  | Quantitative and Qualitative Disclosures about Market Risk                            |  | 19  
|                                                                                                                       |  |                                                                                      
|Item 4.                                                                                                                |  | Controls and Procedures                                                               |  | 19  
|                                                                                                                       | 
|PART II - OTHER INFORMATION                                                                                            |  |                                                                                      
|                                                                                                                       |  |                                                                                      
|Item 1.                                                                                                                |  | Legal Proceedings                                                                     |  | 20  
|                                                                                                                       |  |                                                                                      
|Item 1A.                                                                                                               |  | Risk Factors                                                                          |  | 20  
|                                                                                                                       |  |                                                                                      
|Item 2.                                                                                                                |  | Unregistered Sales of Equity Securities and Use of Proceeds                           |  | 20  
|                                                                                                                       |  |                                                                                      
|Item 3.                                                                                                                |  | Defaults Upon Senior Securities                                                       |  | 20  
|                                                                                                                       |  |                                                                                      
|Item 5.                                                                                                                |  | Other Information                                                                     |  | 20  
|                                                                                                                       |  |                                                                                      
|Item 6.                                                                                                                |  | Exhibits                                                                              |  | 21  



2



---

##### Table of Contents

PART I - FINANCIAL INFORMATION



|Item 1. | FINANCIAL STATEMENTS.
|------- | ---------------------

ENERGY PARTNERS, LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(UNAUDITED)



|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------ |  | ------------ | -------- | - | ---------------- | - | ------- | -
|(In thousands, except share data)                                                                                                                                                    |  | June 30,2010 |          |   | December 31,2009 |  
|ASSETS                                                                                                                                                                               | 
|Current assets:                                                                                                                                                                      |  |              |          |  
|Cash and cash equivalents                                                                                                                                                            |  | $            | 28,188   |   |                  | $ | 26,745  |  
|Trade accounts receivable                                                                                                                                                            |  |              | 23,709   |   |                  |   | 27,958  |  
|Receivables from insurance                                                                                                                                                           |  |              | 3,763    |   |                  |   | 5,464   |  
|Fair value of commodity derivative instruments                                                                                                                                       |  |              | 507      |   |                  |   | 914     |  
|Deferred tax assets                                                                                                                                                                  |  |              | 3,861    |   |                  |   | 5,768   |  
|Prepaid expenses                                                                                                                                                                     |  |              | 3,770    |   |                  |   | 2,940   |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|Total current assets                                                                                                                                                                 |  |              | 63,798   |   |                  |   | 69,789  |  
|Property and equipment  successful efforts method of accounting for oil and natural gas properties                                                                                  |  |              | 675,869  |   |                  |   | 648,517 |  
|Less accumulated depreciation, depletion and amortization                                                                                                                            |  |              | (104,978 | ) |                  |   | (37,535 | )
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|Net property and equipment                                                                                                                                                           |  |              | 570,891  |   |                  |   | 610,982 |  
|Restricted cash                                                                                                                                                                      |  |              | 11,140   |   |                  |   | 22,147  |  
|Other assets                                                                                                                                                                         |  |              | 2,702    |   |                  |   | 3,647   |  
|Deferred financing costs  net of accumulated amortization of $974 at June 30, 2010 and $325 at December 31, 2009                                                                    |  |              | 2,737    |   |                  |   | 2,663   |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|                                                                                                                                                                                     |  | $            | 651,268  |   |                  | $ | 709,228 |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|                                                                                                                                                                                     | 
|LIABILITIES AND STOCKHOLDERS EQUITY                                                                                                                                                 |  |              |          |  
|Current liabilities:                                                                                                                                                                 |  |              |          |  
|Accounts payable                                                                                                                                                                     |  | $            | 17,718   |   |                  | $ | 14,047  |  
|Accrued expenses                                                                                                                                                                     |  |              | 33,742   |   |                  |   | 32,822  |  
|Asset retirement obligations                                                                                                                                                         |  |              | 7,575    |   |                  |   | 10,830  |  
|Current portion of long-term debt                                                                                                                                                    |  |              | 25,000   |   |                  |   | 18,750  |  
|Fair value of commodity derivative instruments                                                                                                                                       |  |              | 4,551    |   |                  |   | 10,256  |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|Total current liabilities                                                                                                                                                            |  |              | 88,586   |   |                  |   | 86,705  |  
|Long-term debt                                                                                                                                                                       |  |              |         |   |                  |   | 58,590  |  
|Asset retirement obligations                                                                                                                                                         |  |              | 64,602   |   |                  |   | 59,150  |  
|Deferred tax liabilities                                                                                                                                                             |  |              | 15,330   |   |                  |   | 16,953  |  
|Fair value of commodity derivative instruments                                                                                                                                       |  |              | 1,166    |   |                  |   | 7,519   |  
|Other                                                                                                                                                                                |  |              | 20       |   |                  |   | 224     |  
|Commitments and contingencies (Note 7)                                                                                                                                               |  |              |          |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|                                                                                                                                                                                     |  |              | 169,704  |   |                  |   | 229,141 |  
|Stockholders equity:                                                                                                                                                                |  |              |          |  
|Preferred stock, $0.001 par value per share. Authorized 1,000,000 shares; no shares issued and outstanding at June 30, 2010
and December 31, 2009                                    |  |              |         |   |                  |   |        |  
|Common stock, $0.001 par value per share. Authorized 75,000,000 shares; shares issued and outstanding 40,090,810 and 40,021,770
at June 30, 2010 and December 31, 2009, respectively |  |              | 40       |   |                  |   | 40      |  
|Additional paid-in capital                                                                                                                                                           |  |              | 502,030  |   |                  |   | 501,059 |  
|Accumulated deficit                                                                                                                                                                  |  |              | (20,506  | ) |                  |   | (21,012 | )
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|Total stockholders equity                                                                                                                                                           |  |              | 481,564  |   |                  |   | 480,087 |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  
|                                                                                                                                                                                     |  | $            | 651,268  |   |                  | $ | 709,228 |  
|                                                                                                                                                                                     |  |              |          |   |                  |   |         |  

See accompanying notes to condensed consolidated financial statements.



3



---

##### Table of Contents

ENERGY PARTNERS, LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)



|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|----------------------------------------------------------------------------------------------------------------------------- |  | ------------------------------- | ------ | - | ----------------------------- | - | ------- | ------------------------------ |  | - | ---------------------------- | - |  | - | ------- | -
|                                                                                                                              |  | Successor Company               |        |   | Predecessor Company           |  
|(In thousands, except per share data)                                                                                         |  | Three MonthsEndedJune 
30, 2010 |        |   | Six MonthsEndedJune 
30, 2010 |   |         | Three MonthsEndedJune 30,
2009 |  |   | Six
MonthsEndedJune 30, 2009 |  
|Revenue:                                                                                                                      |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Oil and natural gas                                                                                                           |  | $                               | 58,163 |   |                               | $ | 128,846 |                                |  | $ | 45,861                       |   |  | $ | 88,511  |  
|Other                                                                                                                         |  |                                 | 34     |   |                               |   | 70      |                                |  |   | 215                          |   |  |   | 265     |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|                                                                                                                              |  |                                 | 58,197 |   |                               |   | 128,916 |                                |  |   | 46,076                       |   |  |   | 88,776  |  
|                                                                                                                              |  |                                 |        |  
|Costs and expenses:                                                                                                           |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Lease operating                                                                                                               |  |                                 | 13,675 |   |                               |   | 28,117  |                                |  |   | 15,044                       |   |  |   | 31,021  |  
|Transportation                                                                                                                |  |                                 | 312    |   |                               |   | 802     |                                |  |   | 293                          |   |  |   | 429     |  
|Exploration expenditures and dry hole costs                                                                                   |  |                                 | 783    |   |                               |   | 2,637   |                                |  |   | 746                          |   |  |   | 1,318   |  
|Impairments                                                                                                                   |  |                                 | 10,885 |   |                               |   | 11,654  |                                |  |   | 1,467                        |   |  |   | 6,580   |  
|Depreciation, depletion and amortization                                                                                      |  |                                 | 26,106 |   |                               |   | 55,961  |                                |  |   | 34,054                       |   |  |   | 66,194  |  
|Accretion of liability for asset retirement obligations                                                                       |  |                                 | 3,222  |   |                               |   | 6,444   |                                |  |   | 1,843                        |   |  |   | 3,677   |  
|General and administrative                                                                                                    |  |                                 | 4,875  |   |                               |   | 9,063   |                                |  |   | 7,584                        |   |  |   | 16,873  |  
|Taxes, other than on earnings                                                                                                 |  |                                 | 2,276  |   |                               |   | 4,313   |                                |  |   | 1,376                        |   |  |   | 2,775   |  
|Loss on abandonment activities                                                                                                |  |                                 | 774    |   |                               |   | 577     |                                |  |   | 118                          |   |  |   | 574     |  
|Other                                                                                                                         |  |                                 | (34    | ) |                               |   | (86     | )                              |  |   | 100                          |   |  |   | (12     | )
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Total costs and expenses                                                                                                      |  |                                 | 62,874 |   |                               |   | 119,482 |                                |  |   | 62,625                       |   |  |   | 129,429 |  
|Business interruption recovery                                                                                                |  |                                 |       |   |                               |   |        |                                |  |   |                             |   |  |   | 1,185   |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Income (loss) from operations                                                                                                 |  |                                 | (4,677 | ) |                               |   | 9,434   |                                |  |   | (16,549                      | ) |  |   | (39,468 | )
|Other income (expense):                                                                                                       |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Interest income                                                                                                               |  |                                 | 88     |   |                               |   | 97      |                                |  |   | 9                            |   |  |   | 47      |  
|Interest expense (contractual interest of $11,028 and $22,741 for the three and six months ended June 30, 2009,
respectively) |  |                                 | (3,945 | ) |                               |   | (8,147  | )                              |  |   | (4,524                       | ) |  |   | (16,237 | )
|Gain (loss) on derivative instruments                                                                                         |  |                                 | 6,957  |   |                               |   | 5,033   |                                |  |   | (923                         | ) |  |   | 2,728   |  
|Loss on extinguishment of debt                                                                                                |  |                                 | (5,627 | ) |                               |   | (5,627  | )                              |  |   |                             |   |  |   |        |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|                                                                                                                              |  |                                 | (2,527 | ) |                               |   | (8,644  | )                              |  |   | (5,438                       | ) |  |   | (13,462 | )
|                                                                                                                              |  |                                 |        |  
|Income (loss) before reorganization items and income taxes                                                                    |  |                                 | (7,204 | ) |                               |   | 790     |                                |  |   | (21,987                      | ) |  |   | (52,930 | )
|                                                                                                                              |  |                                 |        |  
|Reorganization items                                                                                                          |  |                                 |       |   |                               |   |        |                                |  |   | (11,674                      | ) |  |   | (12,602 | )
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|                                                                                                                              |  |                                 |        |  
|Income (loss) before income taxes                                                                                             |  |                                 | (7,204 | ) |                               |   | 790     |                                |  |   | (33,661                      | ) |  |   | (65,532 | )
|Income taxes                                                                                                                  |  |                                 | 2,594  |   |                               |   | (284    | )                              |  |   |                             |   |  |   |        |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Net income (loss)                                                                                                             |  |                                 | (4,610 | ) |                               |   | 506     |                                |  |   | (33,661                      | ) |  |   | (65,532 | )
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Basic earnings (loss) per share                                                                                               |  | $                               | (0.12  | ) |                               | $ | 0.01    |                                |  | $ | (1.05                        | ) |  | $ | (2.04   | )
|Diluted earnings (loss) per share                                                                                             |  | $                               | (0.12  | ) |                               | $ | 0.01    |                                |  | $ | (1.05                        | ) |  | $ | (2.04   | )
|Weighted average common shares used in computing earnings (loss) per share:                                                   |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Basic                                                                                                                         |  |                                 | 40,057 |   |                               |   | 40,049  |                                |  |   | 32,206                       |   |  |   | 32,156  |  
|Effect of dilutive stock options and restricted shares                                                                        |  |                                 |       |   |                               |   | 31      |                                |  |   |                             |   |  |   |        |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  
|Diluted                                                                                                                       |  |                                 | 40,057 |   |                               |   | 40,080  |                                |  |   | 32,206                       |   |  |   | 32,156  |  
|                                                                                                                              |  |                                 |        |   |                               |   |         |                                |  |   |                              |   |  |   |         |  

See accompanying notes to condensed consolidated financial statements.



4



---

##### Table of Contents

ENERGY PARTNERS, LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)



|                                                                                              |  |                                              |         |   |                                                |   |         |  
|--------------------------------------------------------------------------------------------- |  | -------------------------------------------- | ------- | - | ---------------------------------------------- | - | ------- | -
|(In thousands)                                                                                |  | SuccessorCompanySix MonthsEndedJune 30, 2010 |         |   | PredecessorCompanySix MonthsEndedJune 30, 2009 |  
|Cash flows from operating activities:                                                         |  |                                              |         |   |                                                |   |         |  
|Net income (loss)                                                                             |  | $                                            | 506     |   |                                                | $ | (65,532 | )
|Adjustments to reconcile net income (loss) to net cash provided by operating activities:      |  |                                              |         |   |                                                |   |         |  
|Depreciation, depletion and amortization                                                      |  |                                              | 55,961  |   |                                                |   | 66,194  |  
|Accretion of liability for asset retirement obligations                                       |  |                                              | 6,444   |   |                                                |   | 3,677   |  
|Unrealized gain on derivative contracts                                                       |  |                                              | (11,316 | ) |                                                |   |        |  
|Non cash compensation                                                                         |  |                                              | 739     |   |                                                |   | 2,266   |  
|Deferred income taxes                                                                         |  |                                              | 284     |   |                                                |   |        |  
|Repayment of PIK Notes issued for payment of in-kind interest                                 |  |                                              | (3,395  | ) |                                                |   |        |  
|Exploration expenditures                                                                      |  |                                              | 1,827   |   |                                                |   | 28      |  
|Impairments                                                                                   |  |                                              | 11,654  |   |                                                |   | 6,580   |  
|Amortization of deferred financing costs and discount on debt                                 |  |                                              | 457     |   |                                                |   | 8,001   |  
|Loss on abandonment activities                                                                |  |                                              | 577     |   |                                                |   | 574     |  
|Other                                                                                         |  |                                              |        |   |                                                |   | 2       |  
|Changes in operating assets and liabilities:                                                  |  |                                              |         |   |                                                |   |         |  
|Trade accounts receivable                                                                     |  |                                              | 4,249   |   |                                                |   | 8,365   |  
|Other receivables                                                                             |  |                                              | 1,701   |   |                                                |   | 1,544   |  
|Prepaid expenses                                                                              |  |                                              | (830    | ) |                                                |   | 1,126   |  
|Other assets                                                                                  |  |                                              | 622     |   |                                                |   | (128    | )
|Accounts payable and accrued expenses                                                         |  |                                              | 3,003   |   |                                                |   | (9,640  | )
|Other liabilities                                                                             |  |                                              | (4,995  | ) |                                                |   | (13,897 | )
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Net cash provided by operating activities                                                     |  |                                              | 67,488  |   |                                                |   | 9,160   |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Cash flows provided by (used in) investing activities:                                        |  |                                              |         |   |                                                |   |         |  
|Decrease in restricted cash                                                                   |  |                                              | 11,007  |   |                                                |   |        |  
|Property acquisitions                                                                         |  |                                              | (615    | ) |                                                |   | (139    | )
|Exploration and development expenditures                                                      |  |                                              | (26,910 | ) |                                                |   | (27,456 | )
|Other property and equipment additions                                                        |  |                                              | (39     | ) |                                                |   | (129    | )
|Proceeds from sale of oil and gas assets                                                      |  |                                              |        |   |                                                |   | 150     |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Net cash used in investing activities                                                         |  |                                              | (16,557 | ) |                                                |   | (27,574 | )
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Cash flows provided by (used in) financing activities:                                        |  |                                              |         |   |                                                |   |         |  
|Proceeds from indebtedness                                                                    |  |                                              | 20,394  |   |                                                |   | 40,000  |  
|Repayments of indebtedness, excluding repayment of PIK Notes issued to pay interest of $3,395 |  |                                              | (69,882 | ) |                                                |   |        |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Net cash provided by (used in) financing activities                                           |  |                                              | (49,488 | ) |                                                |   | 40,000  |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Net increase in cash and cash equivalents                                                     |  |                                              | 1,443   |   |                                                |   | 21,586  |  
|Cash and cash equivalents at beginning of period                                              |  |                                              | 26,745  |   |                                                |   | 1,991   |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|Cash and cash equivalents at end of period                                                    |  | $                                            | 28,188  |   |                                                | $ | 23,577  |  
|                                                                                              |  |                                              |         |   |                                                |   |         |  
|SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:                                            |  |                                              |         |   |                                                |   |         |  
|Debt incurred to pay deferred financing costs                                                 |  |                                              | 737     |   |                                                |   |        |  

See accompanying notes
to condensed consolidated financial statements.



5



---

##### Table of Contents

ENERGY PARTNERS, LTD. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

(1) BASIS
OF PRESENTATION

Energy Partners, Ltd. (we, our, us, or the Company) was
incorporated as a Delaware corporation on January 29, 1998. We operate as an independent oil and natural gas exploration and production company. Our current operations are concentrated in the shallow to moderate-depth waters in the Gulf of
Mexico focusing on the state and federal waters offshore Louisiana.

On May 1, 2009, we and certain of our subsidiaries
filed voluntary petitions (In re: Energy Partners, Ltd., et. al., Case No. 09-32957) for reorganization under Chapter 11 of Title 11 of the United States Code, 11 U.S.C. §§ 101 et seq., as amended (Chapter 11), in the
United States Bankruptcy Court for the Southern District of Texas, Houston Division (the Bankruptcy Court). On September 21, 2009, we emerged from Chapter 11 reorganization (the Exit Date) pursuant to the plan of
reorganization confirmed by the Bankruptcy Court (the Plan). In accordance with the Plan, the Companys 9.75% Senior Unsecured Notes due 2014 (the Fixed Rate Notes), its Senior Floating Rate Notes due 2013 (the
Floating Rate Notes and together with the Fixed Rate Notes, the Senior Unsecured Notes) and its 8.75% Senior Notes due 2010 (collectively with the Senior Unsecured Notes, the Predecessor Company Notes) and the
related accrued interest were discharged in the reorganization. We converted the Predecessor Company Notes and outstanding Predecessor Company (as defined below) common stock into shares of our new common stock as of the Exit Date. In accordance
with the terms of the Plan, the Predecessor Company Notes and related indentures, as well as the Predecessor Companys outstanding common shares, were cancelled. Each holder of these notes received, in exchange for such holders respective
claim (including principal and accrued interest), such holders pro rata portion of approximately 95% of the common stock in the Successor Company (as defined below), or 38 million shares. Each holder of the Predecessor Companys
common stock received, in full satisfaction of and in exchange for such holders respective common stock interests, such holders pro rata portion of approximately 5% of the common stock in the Successor Company, or approximately
2 million shares. Additional information regarding our reorganization under Chapter 11 is available in our Annual Report on Form 10-K for the year ended December 31, 2009 filed with the Securities and Exchange Commission (the
SEC) on March 11, 2010 (the 2009 Annual Report).

In accordance with Financial Accounting
Standards Board Accounting Standards Codification (ASC) Topic 852 (ASC 852), Reorganizations, we adopted fresh-start accounting as of September 30, 2009. Fresh-start accounting is required upon a substantive
change in control and requires that the reporting entity allocate the reorganization value of the Company to its assets and liabilities in relation to their fair values. Under the provisions of fresh-start accounting, a new entity has been deemed
created for financial reporting purposes. References to the Predecessor Company refer to reporting dates of the Company through September 30, 2009, including the effect of the reorganization and application of fresh-start
accounting; subsequent thereto, the Company is referred to as the Successor Company in the condensed consolidated statements of operations and cash flows and the notes to the condensed consolidated financial statements. The statements of
operations for the three- and six-month periods ended June 30, 2009 and the statement of cash flows for the six-month period ended June 30, 2009 do not reflect the effect of any changes in the Companys capital structure or changes in
fair values of assets and liabilities as a result of fresh-start accounting.

The financial information as of June 30,
2010 and for the three- and six-month periods ended June 30, 2010 and June 30, 2009 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, 2009 has been derived from the audited financial statements at that date.
Certain reclassifications have been made to the prior period financial statements in order to conform to the classification adopted for reporting in the current period. These financial statements and footnotes should be read in conjunction with the
financial statements and notes thereto included in our 2009 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 and the financial information presented for the Successor Company is not comparable to the financial information presented for the Predecessor Company.

(2) EARNINGS PER SHARE

Basic earnings per share is computed by dividing net income available to common stockholders by the weighted average number of common
shares outstanding during each period. Diluted earnings per share includes the effect, if dilutive, of potential common shares associated with stock option and restricted share awards outstanding during each period.



6



---

##### Table of Contents

(3) ASSET RETIREMENT OBLIGATIONS

Changes in our asset retirement obligations were as follows:



|                                                                  |  |                               |        |  
|----------------------------------------------------------------- |  | ----------------------------- | ------ | -
|                                                                  |  | Six Months EndedJune 30, 2010 |       
|                                                                  |  | (in thousands)                |       
|Balance at December 31, 2009                                      |  | $                             | 69,980 |  
|Accretion expense                                                 |  |                               | 6,444  |  
|Revisions                                                         |  |                               | 585    |  
|Liabilities settled                                               |  |                               | (4,832 | )
|                                                                  |  |                               |        |  
|Balance at June 30, 2010                                          |  |                               | 72,177 |  
|Less: Amount required to be settled within the next twelve months |  |                               | (7,575 | )
|                                                                  |  |                               |        |  
|Balance at June 30, 2010, noncurrent asset retirement obligations |  | $                             | 64,602 |  
|                                                                  |  |                               |        |  

(4) INDEBTEDNESS

Total indebtedness was as follows:



|                                                                                                                                                                                                                                     |  |              |        |                  |   |       
|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------ |  | ------------ | ------ | ---------------- | - | ------
|(In thousands)                                                                                                                                                                                                                       |  | June 30,2010 |        | December 31,2009
|Term loan component of Amended Credit Facility, interest rate of 7.5% on June 30, 2010, based on base rate plus a floating
spread, payable in six equal monthly installments of principal from July 28, 2010 to December 28, 2010    |  | $            | 25,000 |                  | $ |      
|Term loan component of Credit Facility, interest rate of 6.5% on December 31, 2009, based on base rate plus a floating
spread, payable in twelve equal monthly installments of principal from October 21, 2009 to September 21, 2010 |  |              |       |                  |   | 18,750
|PIK Notes, face amount of $61.1 million, interest rate of 20%, payable September 21, 2014 (net of $5.9 million of
unamortized original issue discount)                                                                               |  |              |       |                  |   | 55,195
|In-kind interest on PIK Notes (new notes issued January 1, 2010), face amount of $3.4 million, interest rate of 20%, payable
September 21, 2014                                                                                      |  |              |       |                  |   | 3,395 
|                                                                                                                                                                                                                                     |  |              |        |                  |   |       
|Total indebtedness                                                                                                                                                                                                                   |  |              | 25,000 |                  |   | 77,340
|Current portion of indebtedness                                                                                                                                                                                                      |  |              | 25,000 |                  |   | 18,750
|                                                                                                                                                                                                                                     |  |              |        |                  |   |       
|Noncurrent portion of indebtedness                                                                                                                                                                                                   |  | $            |       |                  | $ | 58,590
|                                                                                                                                                                                                                                     |  |              |        |                  |   |       

On June 16, 2010, we entered into an amendment
(the First Amendment) to our Credit Facility dated as of September 21, 2009, (the Credit Facility) (together with the First Amendment, the Amended Credit Facility) with General Electric Capital Corporation,
as administrative agent (the Agent), and the lender parties thereto (the Lenders). Upon its effectiveness on June 28, 2010, the Amended Credit Facility established a $70 million borrowing base consisting of (a) a
new $25 million term loan payable, with interest, in six equal monthly installments of principal from July 28, 2010 to December 28, 2010 and (b) a revolving credit facility with a three-year term that may be used for revolving credit
loans and letters of credit up to an initial maximum principal amount of $45 million. The interest rate spread on loans and letters of credit under the Amended Credit Facility are based on the level of utilization and will range from 3.75% to 4.25%
for base rate borrowings and 4.75% to 5.25% for LIBOR borrowings. The First Amendment contains the Lenders consent for us to redeem all outstanding principal and pay all accrued interest on our 20% Senior Subordinated Secured PIK Notes due
2014 (the PIK Notes), which redemption occurred on June 28, 2010 and was a condition to the effectiveness of the First Amendment.

The redemption price of the PIK Notes, all of which were redeemed, was 100% of the outstanding aggregate principal amount. In connection
with the redemption, we paid a total of $70.9 million of principal and accrued interest. We recorded a loss on the redemption of $5.6 million representing the total of the unamortized original issue discount and unamortized deferred financing costs
associated with the PIK Notes.



7



---

##### Table of Contents

The First Amendment does not make any material changes to the covenants, default provisions
or collateral requirements under the Credit Facility. Our obligations under the Amended Credit Facility and under derivative contracts are guaranteed by our material subsidiaries and secured by our real property assets and the oil and natural
gas properties to which 90% of the present value of our proved reserves is attributable. The documentation for our Amended Credit Facility continues to provide security for our obligations arising from derivative contracts with a party who was
previously a lender (the Derivative Counterparty) under the Credit Facility. Repayment of our term loan obligation to the Derivative Counterparty under the Credit Facility in connection with the execution of the First Amendment resulted
in a Collateral Event as defined in the governing agreements applicable to the derivative contracts with the Derivative Counterparty. As a result, the Derivative Counterparty may request that we provide additional collateral reasonably
satisfactory to the Derivative Counterparty, as described in the agreements governing this derivative transaction, as amended, by October 31, 2010. Alternatively, we may novate our derivative contracts prior to October 31, 2010. Should we
fail to perform in accordance with the derivative transaction governing agreements, as amended, the Derivative Counterpartys remedies may include liquidation of the derivative contracts, which could result in material cash payments the amount
of which would depend on the fair values of the derivative contracts at that time. Our estimated fair value of the obligations under derivative contracts subject to the collateral requirements described above was $5.7 million as of June 30,
2010.

The borrowing base of $70 million under the Amended Credit Facility at June 30, 2010 includes the $25 million
balance on the term loan. The maximum amount of letters of credit that may be outstanding at any one time is $20 million, and the amount available under the revolving credit facility is limited by the borrowing base. The borrowing base is subject to
semi-annual redeterminations based on the proved reserves of the oil and natural gas properties that serve as collateral for the Amended Credit Facility. Monthly scheduled repayments of principal on the term loan, each in the amount of $4.2 million,
reduce the borrowing base by the amount of such repayments.

(5) DERIVATIVE TRANSACTIONS

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 put contracts limit our exposure to declines in the sales price of oil for a limited amount 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 related production. Derivative contracts are carried at their fair value on the condensed consolidated balance sheets as Fair value of commodity derivative instruments and in
Other assets, 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.

As of June 30, 2010, the following derivative instruments were outstanding:

Oil Contracts



|                          |  |                          |  |               |  |                          |       |                          |       |              |         |                   |   |      
|------------------------- |  | ------------------------ |  | ------------- |  | ------------------------ | ----- | ------------------------ | ----- | ------------ | ------- | ----------------- | - | -----
|                          |  | Fixed-Price Swaps        |  | Puts         
|Remaining Contract Term   |  | DailyAverageVolume(Bbls) |  | Volumes(Bbls) |  | AverageSwap Price($/Bbl) |       | DailyAverageVolume(Bbls) |       | Volume(Bbls) |         | FloorPrice($/Bbl)
|July 2010                 |  | 2,700                    |  | 83,700        |  | $                        | 68.84 |                          | 503   |              | 15,600  |                   | $ | 60.00
|August 2010November 2010 |  | 625                      |  | 76,200        |  | $                        | 69.65 |                          | 1,673 |              | 204,150 |                   | $ | 60.00
|December 2010             |  | 1,200                    |  | 37,200        |  | $                        | 70.37 |                          | 1,302 |              | 40,350  |                   | $ | 60.00
|January 2011July 2011    |  | 2,261                    |  | 479,250       |  | $                        | 71.13 |                          | 502   |              | 106,500 |                   | $ | 60.00
|August 2011November 2011 |  | 502                      |  | 61,200        |  | $                        | 72.18 |                          | 1,301 |              | 158,700 |                   | $ | 60.00
|December 2011             |  | 948                      |  | 29,400        |  | $                        | 72.64 |                          | 1,302 |              | 40,350  |                   | $ | 60.00

All of our commodity
derivative instruments are with the Derivative Counterparty, as further described in Note 4. See Note 4 for information regarding collateral requirements related to our derivative instruments.

The following table presents information about the components of gain (loss) on derivative instruments:



|                                                   |  |                           |        |   |                          |   |        |                           |  |   |                          |   |  |   |      
|-------------------------------------------------- |  | ------------------------- | ------ | - | ------------------------ | - | ------ | ------------------------- |  | - | ------------------------ | - |  | - | -----
|                                                   |  | Successor Company         |        |   | Predecessor Company     
|                                                   |  | Three MonthsEndedJune 30, |        |   | Six Months
EndedJune 30, |   |        | Three MonthsEndedJune 30, |  |   | Six Months
EndedJune 30,
|                                                   |  | 2010                      |        |   | 2010                     |   |        | 2009                      |  |   | 2009                    
|                                                   |  | (in thousands)           
|Derivative contracts:                              |  |                           |        |   |                          |   |        |                           |  |   |                          |   |  |   |      
|Unrealized gain due to change in fair market value |  | $                         | 9,580  |   |                          | $ | 11,316 |                           |  | $ |                         |   |  | $ |     
|Realized gain (loss) on settlement                 |  |                           | (2,623 | ) |                          |   | (6,283 | )                         |  |   | (923                     | ) |  |   | 2,728
|                                                   |  |                           |        |   |                          |   |        |                           |  |   |                          |   |  |   |      
|Total gain (loss) on derivative instruments        |  | $                         | 6,957  |   |                          | $ | 5,033  |                           |  | $ | (923                     | ) |  | $ | 2,728
|                                                   |  |                           |        |   |                          |   |        |                           |  |   |                          |   |  |   |      



8



---

##### Table of Contents

(6) FAIR VALUE MEASUREMENTS

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, 2010, 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 derivative instruments were measured using price inputs published by NYMEX. These price inputs are 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. The following table presents our assets and liabilities that are measured at fair value on a recurring basis:



|                                               |  |                     |        |   |                 |   |        |                                       |  |                                           |   |  |                                        |        |   |  |   |  
|---------------------------------------------- |  | ------------------- | ------ | - | --------------- | - | ------ | ------------------------------------- |  | ----------------------------------------- | - |  | -------------------------------------- | ------ | - |  | - | -
|                                               |  | As of June 30, 2010
|                                               |  |                     |        |   |                 |   |        | Fair Value Measurements Using:       
|                                               |  | CarryingAmount      |        |   | Total FairValue |   |        | QuotedPrices inActiveMarkets(Level 1) |  | SignificantOtherObservableInputs(Level 2) |   |  | SignificantUnobservableInputs(Level 3)
|Financial Assets (Liabilities) (in thousands): |  |                     |        |   |                 |   |        |                                       |  |                                           |   |  |                                        |        |   |  |   |  
|Derivative instruments                         |  | $                   | 1,399  |   |                 | $ | 1,399  |                                       |  | $                                         |  |  | $                                      | 1,399  |   |  | $ | 
|Derivative instruments                         |  | $                   | (5,717 | ) |                 | $ | (5,717 | )                                     |  | $                                         |  |  | $                                      | (5,717 | ) |  | $ | 

The fair
value of our variable rate debt under our Amended Credit Facility approximated the carrying amount at June 30, 2010.

On
June 29, 2010, we entered into a wind storm agreement with an insurance company. Under this agreement, if a named wind storm occurs in a specified area of the Gulf of Mexico and that storm meets certain strength criteria, the insurance company
will pay cash proceeds to us of $6.9 million. We paid a premium of $0.9 million for this agreement, and the agreement terminates in December 2010. This wind storm agreement is considered a weather derivative under the applicable authoritative
guidance related to financial instruments. We recognized the premium paid as a current asset which will be amortized to expense over the six-month term of the agreement. At June 30, 2010, we estimate that the fair value of this financial
instrument approximates the amount of the premium paid.

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 a lease). An impairment loss is indicated if estimated 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 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 meet the definition of Level 3 inputs within the fair value hierarchy. Impairment expense for the three- and six-month periods ended June 30, 2010 was primarily related to two producing fields which were determined to have future net
cash flows less than their carrying values due primarily to reservoir performance resulting in the write down of these properties to their estimated fair values as of June 30, 2010.

(7) COMMITMENTS AND CONTINGENCIES

We maintain restricted escrow funds in a trust for future plugging, abandonment and other decommissioning costs at our East Bay field. The
trust was originally funded with $15 million and, with accumulated interest, increased to $16.7 million at December 31, 2008. We may draw from the trust upon the authorization, and subsequent completion, of qualifying abandonment activities at
our East Bay field. At June 30, 2010, we had $11.1 million remaining in restricted escrow funds for decommissioning work in our East Bay field, $5.1 million of which will be available for draw upon authorization, and subsequent completion, of
additional qualifying decommissioning activities as that work progresses. The remaining $6.0 million will remain restricted until substantially all required decommissioning in the East Bay field is complete. Through June 30, 2010, we had made
draws of $5.6 million. During July 2010, we made an additional draw of $1.1 million. Amounts on deposit in the trust account are reflected in Restricted cash in the accompanying 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 date back to 2006. The oil purchasers initial estimate of the oil volumes misallocated to us was approximately 74,000 barrels, which may be valued at up to $6.9 million based on information
provided by the oil purchaser. We have previously recorded an amount that we believe may be payable related to a potential reallocation, which amount is reflected in accrued expenses in the accompanying condensed consolidated balance sheet as of
June 30, 2010.



9



---

##### Table of Contents

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. 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.



|Item 2. | MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.
|------- | --------------------------------------------------------------------------------------

Statements we make in this Quarterly Report on Form 10-Q (the Quarterly Report) which express a belief, expectation or
intention, as well as those that are not historical fact, may constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Our forward-looking statements are subject to various risks,
uncertainties and assumptions, including those to which we refer under the headings Cautionary Statement Concerning Forward-Looking Statements and Risk Factors in Items 1 and 1A of Part 1 of our 2009 Annual Report.

OVERVIEW

The Company was incorporated as a Delaware corporation in January 1998 and operates as an independent oil and natural gas exploration and
production company. Our current operations are concentrated in the shallow to moderate-depth waters in the Gulf of Mexico focusing on the state and federal waters offshore Louisiana.

We maintain a website at www.eplweb.com that contains information about us, including links to our Annual Reports on
Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and all related amendments as soon as reasonably practicable after providing such reports to the SEC.

We use the successful efforts method of accounting for oil and natural gas producing activities. Under this method, we capitalize lease
acquisition costs, costs to drill and complete exploration wells in which proven reserves are discovered and costs to drill and complete development wells. Exploratory drilling costs are charged to expense if and when activities result in no
reserves in commercial quantities. Seismic, geological and geophysical, and delay rental expenditures are expensed as they are incurred. We conduct various exploration and development activities jointly with others and, accordingly, recorded amounts
for our oil and natural gas properties reflect only our proportionate interest in such activities. Our 2009 Annual Report includes a discussion of our critical accounting policies, which have not changed significantly since the end of the last
fiscal year.

We produce both oil and natural gas. Throughout this Quarterly Report, when we refer to total
production, total reserves, percentage of production, percentage of reserves, or any similar term, we have converted our natural gas reserves or production into barrel equivalents. For this purpose, six
thousand cubic feet of natural gas is equal to one barrel of oil, which is based on the relative energy content of natural gas and oil. Natural gas liquids are aggregated with oil in this Quarterly Report.

Outlook

Our reorganization under Chapter 11 in 2009 restructured our balance sheet and substantially reduced our indebtedness, providing for an
improved capital structure and enhanced financial flexibility. Since the reorganization, we have continued to improve our financial strength, repaying all of our high yield PIK Notes and entering into the Amended Credit Facility, which provides us
with a borrowing base of $70 million and availability under the revolving credit portion of $45 million as of June 30, 2010.

We entered 2010 with a continuing focus on 1) achieving meaningful cost reductions in general and administrative (G&A)
expenses and lease operating expenses (LOE); 2) converting non-producing reserves to cash flow; and 3) developing a core competency in plugging, abandonment and decommissioning operations. We allocate capital in a rigorous and
disciplined manner intended to achieve an overall lower risk capital expenditure profile that focuses on maximizing rate of return and requires projects to compete on that basis.

While we expect that our 2010 average oil production levels will exceed our 2009 levels, we expect our
overall production in barrels of oil equivalent to decline in 2010 as a result of natural gas production declines that occurred in the second half of 2009 that have continued through the first half of 2010 and are expected to continue for the
remainder of 2010. Prior to 2010, we established an initial low-risk capital budget oriented towards stabilizing production at the levels experienced in the quarter ended December 31, 2009 and have since continued to develop additional
production enhancing opportunities to be considered in 2010 and 2011, some of which have been approved in excess of our initial capital budget. As of the date of this filing, our authorized exploration and development capital budget is $64 million,
as compared with an initial capital budget at the first of the year of $45 million. At this capital budget level, we estimate that our overall production in barrels of oil equivalent will decline during the remainder of 2010 and in 2011. Our key
areas of operations and our plans for future exploration and development activities do not include any deepwater areas. Additionally, we have meaningful acreage and exploitation, development and exploration opportunities in the state waters offshore
Louisiana. As a result, our plans have not been materially impacted by the recently announced regulatory actions taken with respect to leases in federal waters. However, the recent Deepwater Horizon incident has affected our ability to secure
certain equipment necessary to conduct simultaneous drilling operations in our East Bay field.



10



---

##### Table of Contents

We continue to focus on growth opportunities within our existing development portfolio and
strategic opportunities to take advantage of our improved capital structure and enhanced financial flexibility. These opportunities, for which we do not budget, include acquiring assets. We continue to evaluate our existing portfolio of undeveloped
leases for exploration opportunities, and we will consider purchasing interests in undeveloped leaseholds and participating in third party drilling opportunities to complement our existing asset base. In light of the recent regulatory actions taken
with respect to leases in federal waters, it is unclear when the federal government will offer additional offshore acreage for lease.

We continue to focus on our core competency in plugging, abandonment and decommissioning operations in an attempt to maximize
efficiencies and reduce our overall costs in that area of operations. We expect these efforts will enable us to achieve our objectives of prudently removing idle infrastructure throughout the remaining productive lives of our fields and, over time,
reducing ongoing LOE associated with maintaining idle infrastructure.

We continue to generate prospects, strive to maintain
an extensive inventory of drillable prospects in-house and maintain exposure to new opportunities through relationships with industry partners. Generally, we attempt to fund any exploration and development expenditures with internally generated cash
flows.

Our drilling program has been more active in 2010 compared to 2009, though our initial capital budget was scheduled
predominantly for the first half of 2010. Our longer term operating strategy is to increase our oil and natural gas reserves and production while focusing on reducing exploration and development costs and operating costs to be competitive with our
offshore Gulf of Mexico industry peers.

Our revenue, profitability and future growth rate depend substantially on factors
beyond our control, such as oil and natural gas prices, tropical weather, economic, political and regulatory developments and availability of other sources of energy. Oil and natural gas prices historically have been volatile and may fluctuate
widely in the future. Sustained periods of low prices for oil and natural gas could materially adversely affect our financial position, our results of operations, the quantities of oil and natural gas reserves that we can economically produce and
our access to capital. See Risk Factors in Item 1A of our 2009 Annual Report and Item 1A of Part II of this Quarterly Report for a more detailed discussion of these risks.

Results of Operations

Our Chapter 11 reorganization did not result in the disposition of any of our oil and natural gas properties. As a result, the
comparability of certain components of our operating results and key operating performance measures, specifically those related to production, average oil and natural gas selling prices, revenues and LOE, was not significantly impacted by the
reorganization. For accounting purposes, the Predecessor Companys operations are deemed to have ceased on September 30, 2009, and a new entity is deemed to have begun operations as of that date. As a result, the condensed consolidated
financial statements of the Predecessor Company are not comparable to those of the Successor Company. For those items that are not comparable, we have included additional analysis to supplement the discussion. The following line items in our
condensed consolidated statements of operations for the three and six months ended June 30, 2010 are not comparable to the three and six months ended June 30, 2009 due to our reorganization and application of fresh-start accounting:



| |  |  | Depreciation, depletion and amortization;
| | - |  | -----------------------------------------



| |  |  | Accretion of liability for asset retirement obligations;
| | - |  | --------------------------------------------------------



| |  |  | Income (loss) from operations;
| | - |  | ------------------------------



| |  |  | Interest expense;
| | - |  | -----------------



| |  |  | Income (loss) before reorganization items and income taxes;
| | - |  | -----------------------------------------------------------



| |  |  | Income (loss) before income taxes; and
| | - |  | --------------------------------------



| |  |  | Net income (loss).
| | - |  | ------------------

Three Months Ended June 30, 2010

During the three months ended June 30, 2010, we completed eight (8) recompletion operations, seven (7) of which were
successful; three (3) exploratory drilling operations, all of which were successful; and one (1) development well which was successful.



11



---

##### Table of Contents

Our operating results for the three months ended June 30, 2010, compared to the three
months ended June 30, 2009, reflect higher average selling prices for both our oil and natural gas and declines in LOE and G&A expenses. Additionally, our product mix reflects an increase in oil production and a decline in natural gas
production. Our average daily production of both oil and natural gas has declined in the three months ended June 30, 2010 as compared to the three months ended March 31, 2010. We expect that this trend will continue during 2010 and into
the first half of 2011.

For the three months ended June 30, 2010, our revenues increased 26% as compared to the three
months ended June 30, 2009 due primarily to higher average selling prices for our oil production and the increase in oil production. Our overall production volumes declined by 14%, on a barrel equivalent basis, for the three months ended
June 30, 2010 when compared to the three months ended June 30, 2009.

Our Gulf of Mexico shelf production decreased
in the three months ended June 30, 2010, as compared to the three months ended June 30, 2009, due primarily to natural reservoir declines in the second half of 2009 and continuing into the first half of 2010. Our deepwater production,
primarily natural gas, declined for the quarter ended June 30, 2010, as compared to the quarter ended June 30, 2009, due primarily to natural reservoir decline from our deepwater well. We expect that our deepwater production will continue
to decline in the future.

In addition to the items addressed above, our net loss for the three months ended June 30,
2010, as compared to the net loss for the three months ended June 30, 2009, reflects an increase in impairments and a $5.6 million loss on extinguishment of debt resulting from redemption of the PIK Notes. Our net loss for the three months
ended June 30, 2009 also includes $11.7 million in costs associated with the reorganization.

Our effective tax rate for
the three months ended June 30, 2010 was 36%. Our effective tax rate for the three months ended June 30, 2009 was zero because we provided a valuation allowance against the net deferred tax assets generated during the three months ended
June 30, 2009.

Six Months Ended June 30, 2010

During the six months ended June 30, 2010, we completed thirteen (13) recompletion operations, eleven (11) of which were
successful; five (5) exploratory drilling operations, four (4) of which were successful; and one (1) development well which was successful.

Our operating results for the six months ended June 30, 2010, compared to the six months ended June 30, 2009, reflect higher
average selling prices for both our oil and natural gas and declines in LOE and G&A expenses. Additionally, our product mix reflects an increase in oil production and a decrease in natural gas production for the six months ended June 30,
2010 as compared to the six months ended June 30, 2009.

For the six months ended June 30, 2010, our revenues
increased 45% as compared to the six months ended June 30, 2009 due primarily to significantly higher average selling prices for our oil production and the increase in oil production. Our overall production volumes declined by 5%, on a barrel
equivalent basis, for the six months ended June 30, 2010 when compared to the six months ended June 30, 2009.

Our
Gulf of Mexico shelf production decreased in the six months ended June 30, 2010, as compared to the six months ended June 30, 2009, due primarily to natural reservoir declines in the second half of 2009 and continuing into the first half
of 2010. Our deepwater production, primarily natural gas, declined for the six months ended June 30, 2010, as compared to the six months ended June 30, 2009, which was due primarily to natural reservoir decline from our deepwater well. We
expect that our deepwater production will continue to decline in the future.

In addition to the items addressed above, our
net income for the six months ended June 30, 2010, as compared to the net loss for the six months ended June 30, 2009, reflects an increase in impairments, significant reductions in interest expense due primarily to our reorganization and
a $5.6 million loss on extinguishment of debt resulting from redemption of the PIK Notes. Our net loss for the six months ended June 30, 2009 also includes $12.6 million in costs associated with the reorganization.

Our effective tax rate for the six months ended June 30, 2010 was 36%. Our effective tax rate for the six months ended June 30,
2009 was zero because we provided a valuation allowance against the net deferred tax assets generated during the six months ended June 30, 2009.



12



---

##### Table of Contents

RESULTS OF OPERATIONS

The following table presents information about our oil and natural gas operations:



|                                                                                      |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|------------------------------------------------------------------------------------- |  | -------------------------- | ------ | - | ------------------------ | - | ------ | ---------------- |  | - | ------------------ | - |  | - | ------
|                                                                                      |  | SuccessorCompany           |        |   | PredecessorCompany       |   |        | SuccessorCompany |  |   | PredecessorCompany
|                                                                                      |  | Three Months EndedJune 30, |        |   | Six Months EndedJune 30,
|                                                                                      |  | 2010                       |        |   | 2009                     |   |        | 2010             |  |   | 2009              
|Net production (per day):                                                             |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Oil (Bbls)                                                                            |  |                            | 6,411  |   |                          |   | 5,167  |                  |  |   | 6,817              |   |  |   | 5,195 
|Natural gas (Mcf)                                                                     |  |                            | 43,549 |   |                          |   | 64,679 |                  |  |   | 47,220             |   |  |   | 62,047
|Total barrels of oil equivalent                                                       |  |                            | 13,669 |   |                          |   | 15,947 |                  |  |   | 14,687             |   |  |   | 15,536
|Average sales prices, excluding impact of derivatives:                                |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Oil (per Bbl)                                                                         |  | $                          | 70.54  |   |                          | $ | 51.31  |                  |  | $ | 71.01              |   |  | $ | 44.07 
|Natural gas (per Mcf)                                                                 |  |                            | 4.29   |   |                          |   | 3.69   |                  |  |   | 4.82               |   |  |   | 4.19  
|Total (per Boe)                                                                       |  |                            | 46.76  |   |                          |   | 31.60  |                  |  |   | 48.47              |   |  |   | 31.48 
|Oil and natural gas revenues (in thousands):                                          |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Oil                                                                                   |  | $                          | 41,149 |   |                          | $ | 24,124 |                  |  | $ | 87,616             |   |  | $ | 41,440
|Natural gas                                                                           |  |                            | 17,014 |   |                          |   | 21,737 |                  |  |   | 41,230             |   |  |   | 47,071
|                                                                                      |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Total                                                                                 |  |                            | 58,163 |   |                          |   | 45,861 |                  |  |   | 128,846            |   |  |   | 88,511
|Impact of derivatives instruments settled during the period (1):                      |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Oil (per Bbl)                                                                         |  | $                          | (4.66  | ) |                          | $ | 5.11   |                  |  | $ | (5.17              | ) |  | $ | 2.71  
|Natural gas (per Mcf)                                                                 |  | $                          | 0.02   |   |                          | $ | (0.57  | )                |  | $ | 0.01               |   |  | $ | 0.02  
|Average costs (per Boe):                                                              |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|LOE                                                                                   |  | $                          | 10.99  |   |                          | $ | 10.37  |                  |  | $ | 10.58              |   |  | $ | 11.03 
|Depreciation, depletion and amortization (DD&A)                                       |  |                            | 20.99  |   |                          |   | 23.47  |                  |  |   | 21.05              |   |  |   | 23.54 
|Accretion of liability for asset retirement obligations                               |  |                            | 2.59   |   |                          |   | 1.27   |                  |  |   | 2.42               |   |  |   | 1.31  
|Taxes, other than on earnings                                                         |  |                            | 1.83   |   |                          |   | 0.95   |                  |  |   | 1.62               |   |  |   | 0.99  
|G&A expenses                                                                          |  |                            | 3.92   |   |                          |   | 5.23   |                  |  |   | 3.41               |   |  |   | 6.00  
|Increase (decrease) in oil and natural gas revenues between periods presented due to: |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Changes in prices of oil                                                              |  | $                          | 9,041  |   |                          |   |        |                  |  | $ | 25,330             |   |  |   |       
|Changes in production volumes of oil                                                  |  |                            | 7,984  |   |                          |   |        |                  |  |   | 20,846             |   |  |   |       
|                                                                                      |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Total increase in oil sales                                                           |  |                            | 17,025 |   |                          |   |        |                  |  |   | 46,176             |   |  |   |       
|Changes in prices of natural gas                                                      |  | $                          | 3,536  |   |                          |   |        |                  |  | $ | 7,052              |   |  |   |       
|Changes in production volumes of natural gas                                          |  |                            | (8,259 | ) |                          |   |        |                  |  |   | (12,893            | ) |  |   |       
|                                                                                      |  |                            |        |   |                          |   |        |                  |  |   |                    |   |  |   |       
|Total decrease in natural gas sales                                                   |  |                            | (4,723 | ) |                          |   |        |                  |  |   | (5,841             | ) |  |   |       



|(1) | See Other Income and Expense section for further discussion of the impact of derivative instruments.
|--- | ----------------------------------------------------------------------------------------------------

Three Months Ended June 30, 2010 Compared to Three Months Ended June 30, 2009

Revenue and Net Loss



|                             |  |                                               |        |   |                                                  |   |         |          |  |          |        |  |    |  
|---------------------------- |  | --------------------------------------------- | ------ | - | ------------------------------------------------ | - | ------- | -------- |  | -------- | ------ |  | -- | -
|                             |  | SuccessorCompanyThree MonthsEndedJune 30,2010 |        |   | PredecessorCompanyThree MonthsEndedJune 30, 2009 |   |         |          |  |          |       
|                             |  |                                               |        |   | (in thousands)                                   |   |         | $ Change |  | % Change |       
|Oil and natural gas revenues |  | $                                             | 58,163 |   |                                                  | $ | 45,861  |          |  | $        | 12,302 |  | 27 | %
|Net loss                     |  |                                               | (4,610 | ) |                                                  |   | (33,661 | )        |  |          | NM     |  | NM |  



NM  Not Meaningful

Our
oil and natural gas revenues increased primarily due to a 37% increase in average selling prices for our oil and a 24% increase in oil production in the three months ended June 30, 2010 as compared to the three months ended June 30, 2009,
offset by a 33% decline in natural gas production in the three months ended June 30, 2010 as compared to the three months ended June 30, 2009. The percentage of production represented by oil has increased for us. Oil represented 47% of
total production for the three months ended June 30, 2010, as compared to 32% of total production for the three months ended June 30, 2009.



13



---

##### Table of Contents

Operating Expenses

Our operating expenses primarily consist of the following:



|                                            |  |                                               |        |  |                                                 |   |          |  |   |          |   |  |     |   
|------------------------------------------- |  | --------------------------------------------- | ------ |  | ----------------------------------------------- | - | -------- |  | - | -------- | - |  | --- | --
|                                            |  | SuccessorCompanyThree MonthsEndedJune 30,2010 |        |  | PredecessorCompanyThree MonthsEndedJune 30,2009 |   |          |  |   |          |  
|                                            |  |                                               |        |  | (in thousands)                                  |   | $ Change |  |   | % Change |  
|LOE                                         |  | $                                             | 13,675 |  |                                                 | $ | 15,044   |  | $ | (1,369   | ) |  | (9  | )%
|Exploration expenditures and dry hole costs |  |                                               | 783    |  |                                                 |   | 746      |  |   | 37       |   |  | 5   | % 
|Impairments                                 |  |                                               | 10,885 |  |                                                 |   | 1,467    |  |   | 9,418    |   |  | NM  |   
|DD&A, including accretion expense           |  |                                               | 29,328 |  |                                                 |   | 35,897   |  |   | NM       |   |  | NM  |   
|G&A expenses                                |  |                                               | 4,875  |  |                                                 |   | 7,584    |  |   | (2,709   | ) |  | (36 | )%
|Taxes, other than on earnings               |  |                                               | 2,276  |  |                                                 |   | 1,376    |  |   | 900      |   |  | 65  | % 



NM  Not Meaningful

Impairment expense for the three months ended June 30, 2010 was primarily related to two producing fields which were determined to
have future net cash flows less than their carrying values due primarily to reservoir performance resulting in the write down of these properties to their estimated fair values as of June 30, 2010.

G&A expenses, which include cash and non-cash stock based compensation of $0.6 million and $1.0 million in the three months ended
June 30, 2010 and 2009, respectively, decreased in the three months ended June 30, 2010, as compared to the three months ended June 30, 2009, primarily as a result of the impact of cost reduction efforts on the 2010 quarter.

Taxes, other than on earnings, increased in the three months ended June 30, 2010 as compared to the three months ended
June 30, 2009, due primarily to higher average sales prices for oil (which is taxed based on value) and higher estimated property tax assessments in 2010.

Other Income and Expense

Our interest expense was impacted by our reorganization and is not comparable for the periods presented. Interest expense in the three
months ended June 30, 2010 consists primarily of interest expense on our PIK Notes and our Credit Facility. We redeemed all of our outstanding PIK Notes on June 28, 2010. Interest expense in the three months ended June 30, 2009
consists primarily of interest expense on the Predecessor Company Notes. However, we had discontinued accruing interest on the Predecessor Company Notes as of May 1, 2009, the date we filed for reorganization under Chapter 11. As a result of
the Chapter 11 reorganization, each holder of the Predecessor Company Notes received such holders pro rata portion of approximately 95% of the common stock in the Successor Company, and the Predecessor Company Notes were converted into common
stock and discharged in the reorganization.

Other income (expense) in the three months ended June 30, 2010 includes a
net gain of $7.0 million consisting of an unrealized gain of $9.6 million due to the change in fair market value of derivative instruments and a loss of $2.6 million on derivative instruments settled during the quarter primarily from the impact of
our oil fixed-price swaps. Other income (expense) in the three months ended June 30, 2009 includes a net loss of $0.9 million on derivative instruments settled during the quarter. As a result of the liquidity challenges that led to our filing
for reorganization under Chapter 11, we had settled all remaining outstanding derivative contracts during the three months ended June 30, 2009.

Six Months Ended June 30, 2010 Compared to Six Months Ended June 30, 2009

Revenue and Net Income (Loss)



|                             |  |                                             |         |  |                                                |   |         |          |  |          |        |  |    |  
|---------------------------- |  | ------------------------------------------- | ------- |  | ---------------------------------------------- | - | ------- | -------- |  | -------- | ------ |  | -- | -
|                             |  | SuccessorCompanySix MonthsEndedJune 30,2010 |         |  | PredecessorCompanySix MonthsEndedJune 30, 2009 |   |         |          |  |          |       
|                             |  |                                             |         |  | (in thousands)                                 |   |         | $ Change |  | % Change |       
|Oil and natural gas revenues |  | $                                           | 128,846 |  |                                                | $ | 88,511  |          |  | $        | 40,335 |  | 46 | %
|Net income (loss)            |  |                                             | 506     |  |                                                |   | (65,532 | )        |  |          | NM     |  | NM |  



NM  Not Meaningful

Our oil and natural gas revenues increased primarily due to a 61% increase in average selling prices for
our oil and a 31% increase in oil production in the six months ended June 30, 2010 as compared to the six months ended June 30, 2009, offset in part by a 24% decline in natural gas production in the six months ended June 30, 2010 as
compared to the six months ended June 30, 2009. The percentage of production represented by oil has increased for us. Oil represented 46% of total production for the six months ended June 30, 2010, as compared to 33% of total production
for the six months ended June 30, 2009.



14



---

##### Table of Contents

Operating Expenses

Our operating expenses primarily consist of the following:



|                                            |  |                                             |        |  |                                               |   |          |  |   |          |   |  |     |   
|------------------------------------------- |  | ------------------------------------------- | ------ |  | --------------------------------------------- | - | -------- |  | - | -------- | - |  | --- | --
|                                            |  | SuccessorCompanySix MonthsEndedJune 30,2010 |        |  | PredecessorCompanySix MonthsEndedJune 30,2009 |   |          |  |   |          |  
|                                            |  |                                             |        |  | (in thousands)                                |   | $ Change |  |   | % Change |  
|LOE                                         |  | $                                           | 28,117 |  |                                               | $ | 31,021   |  | $ | (2,904   | ) |  | (9  | )%
|Exploration expenditures and dry hole costs |  |                                             | 2,637  |  |                                               |   | 1,318    |  |   | 1,319    |   |  | NM  |   
|Impairments                                 |  |                                             | 11,654 |  |                                               |   | 6,580    |  |   | 5,074    |   |  | 77  | % 
|DD&A, including accretion expense           |  |                                             | 62,405 |  |                                               |   | 69,871   |  |   | NM       |   |  | NM  |   
|G&A expenses                                |  |                                             | 9,063  |  |                                               |   | 16,873   |  |   | (7,810   | ) |  | (46 | )%
|Taxes, other than on earnings               |  |                                             | 4,313  |  |                                               |   | 2,775    |  |   | 1,538    |   |  | 55  | % 



NM  Not Meaningful

We
drilled one (1) exploratory dry hole in the six months ended June 30, 2010, resulting in $1.8 million of dry hole costs. In addition, the expense in the six months ended June 30, 2010 includes $0.8 million of seismic expenditures and
delay rentals. The expense in the six months ended June 30, 2009 is comprised of $1.3 million of seismic expenditures and delay rentals.

Impairment expense for the six months ended June 30, 2010 was primarily related to two producing fields which were determined to
have future net cash flows less than their carrying values due primarily to reservoir performance resulting in the write down of these properties to their estimated fair values as of June 30, 2010. Impairment expense for the six months ended
June 30, 2009 was primarily related to two producing fields which were determined to have future net cash flows less than their carrying values due primarily to commodity price declines and reservoir performance resulting in the write down of
these properties to their estimated fair values.

G&A expenses, which include cash and non-cash stock based compensation
of $0.7 million and $2.5 million in the six months ended June 30, 2010 and 2009, respectively, decreased in the six months ended June 30, 2010, as compared to the six months ended June 30, 2009, primarily as a result of legal and
financial advisory fees associated with our balance sheet restructuring efforts in the 2009 period and the impact of cost reduction efforts on the 2010 period.

Taxes, other than on earnings, increased in the six months ended June 30, 2010 as compared to the six months ended June 30,
2009, due primarily to higher average sales prices for oil (which is taxed based on value) and higher estimated property tax assessments in 2010.

Other Income and Expense

Our interest expense was impacted by our Chapter 11 reorganization and is not comparable for the periods presented. Interest expense in
the six months ended June 30, 2010 consists primarily of interest expense on our PIK Notes and our Credit Facility. We redeemed all of our outstanding PIK Notes on June 28, 2010. Interest expense in the six months ended June 30, 2009
consists primarily of interest expense on the Predecessor Company Notes. However, as described above, we had discontinued accruing interest on the Predecessor Company Notes as of May 1, 2009, the date we filed for reorganization under Chapter
11, and the Predecessor Company Notes were discharged in the reorganization.

Other income (expense) in the six months ended
June 30, 2010 includes a net gain of $5.0 million consisting of an unrealized gain of $11.3 million due to the change in fair market value of derivative instruments and a loss of $6.3 million on derivative instruments settled during the period
primarily from the impact of our oil fixed-price swaps. Other income (expense) in the six months ended June 30, 2009 includes a net gain of $2.7 million on derivative instruments settled during the period primarily from the impact of a decline
in oil and natural gas selling prices during 2009. As a result of the liquidity challenges that led to our filing for reorganization under Chapter 11, we had settled all of our outstanding derivative contracts during the six months ended
June 30, 2009.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity and Capital Resources

A key focus of management in 2010 was to reduce our cost of capital. In June 2010, we reached an agreement
(described below) to amend our $125 million Senior Secured Credit Facility with General Electric Capital Corporation, which enabled us to redeem our PIK Notes. On June 28, 2010, we paid a total of $70.9 million of principal and accrued interest
in connection with the redemption of the PIK Notes. We redeemed all of the PIK Notes at 100% of the outstanding aggregate principal amount, plus accrued and unpaid interest. As a result, we recorded a loss on extinguishment of debt totaling $5.6
million which represents the total of the unamortized original issue discount and unamortized deferred financing costs associated with the PIK Notes. We used cash on hand and a portion of the proceeds of the new term loan under the Amended Credit
Facility to fund the redemption.



15



---

##### Table of Contents

On June 16, 2010, we entered into an amendment (the First Amendment) to our
Credit Facility dated as of September 21, 2009, (the Credit Facility) (together with the First Amendment, the Amended Credit Facility) with General Electric Capital Corporation, as administrative agent (the
Agent), and the lender parties thereto (the Lenders). Upon its effectiveness on June 28, 2010, the Amended Credit Facility established a $70 million borrowing base consisting of (a) a new $25 million term loan
payable, with interest, in six equal monthly installments of principal from July 28, 2010 to December 28, 2010 and (b) a revolving credit facility with a three-year term that may be used for revolving credit loans and letters of
credit up to an initial maximum principal amount of $45 million. The interest rate spread on loans and letters of credit under the Amended Credit Facility are based on the level of utilization and will range from 3.75% to 4.25% for base rate
borrowings and 4.75% to 5.25% for LIBOR borrowings. The First Amendment contains the Lenders consent for us to redeem all outstanding principal and pay all accrued interest on our PIK Notes, which redemption occurred on June 28, 2010 and
was a condition to the effectiveness of the First Amendment.

The First Amendment does not make any material changes to the
covenants, default provisions or collateral requirements under the Credit Facility. Our obligations under the Amended Credit Facility and under derivative contracts are guaranteed by our material subsidiaries and secured by our real property assets
and the oil and natural gas properties to which 90% of the present value of our proved reserves is attributable. The documentation for our Amended Credit Facility continues to provide security for our obligations arising from derivative
contracts with a party who was previously a lender (the Derivative Counterparty) under the Credit Facility. Repayment of our term loan obligation to the Derivative Counterparty under the Credit Facility in connection with the execution
of the First Amendment resulted in a Collateral Event as defined in the governing agreements applicable to the derivative contracts with the Derivative Counterparty. As a result, the Derivative Counterparty may request that we provide
additional collateral reasonably satisfactory to the Derivative Counterparty, as described in the agreements governing this derivative transaction, as amended, by October 31, 2010. Alternatively, we may novate our derivative contracts prior to
October 31, 2010. Should we fail to perform in accordance with the derivative transaction governing agreements, as amended, the Derivative Counterpartys remedies may include liquidation of the derivative contracts, which could result in
material cash payments the amount of which would depend on the fair values of the derivative contracts at that time. Our estimated fair value of the obligations under derivative contracts subject to the collateral requirements described above was
$5.7 million as of June 30, 2010.

The borrowing base of $70 million under the Amended Credit Facility at June 30,
2010 includes the $25 million balance on the term loan. The maximum amount of letters of credit that may be outstanding at any one time is $20 million, and the amount available under the revolving credit facility is limited by the borrowing base.
The borrowing base is subject to semi-annual redeterminations based on the proved reserves of the oil and natural gas properties that serve as collateral for the Amended Credit Facility. Monthly scheduled repayments of principal on the term loan,
each in the amount of $4.2 million, reduce the borrowing base by the amount of such repayments.

As of June 30, 2010, we
had Cash and cash equivalents of $28.2 million and no borrowings outstanding under the revolver component of the Amended Credit Facility. The undrawn commitment under the Amended Credit Facility was $45 million as of that date. We had total
indebtedness of $25 million consisting of the term loan component of the Amended Credit Facility. As of July 31, 2010, the Cash and cash equivalents on our balance sheet has increased and we have reduced the amount outstanding under the Amended
Credit Facility by the July 2010 term loan principal payment of $4.2 million.

We entered 2010 with a capital budget of
approximately $57 million, of which approximately $45 million was allocated for exploration and development expenditures and $12 million for plugging, abandonment and other decommissioning expenditures. As of the date of this filing, our authorized
exploration and development capital budget is $64 million. At this capital budget level, we estimate that our overall production in barrels of oil equivalent will decline during the remainder of 2010 and in 2011. Further, we expect that our oil and
natural gas reserves will decline as of December 31, 2010 as compared to December 31, 2009. Our key areas of operations and our plans for future exploration and development activities do not include any deepwater areas. Additionally, we
have meaningful acreage and exploitation, development and exploration opportunities in the state waters of offshore Louisiana. As a result, our plans have not been materially impacted by the recently announced regulatory actions taken with respect
to leases in federal waters. However, the recent Deepwater Horizon incident has affected our ability to secure certain equipment necessary to conduct simultaneous drilling operations in our East Bay field.

We continue to focus on growth opportunities within our existing development portfolio and strategic opportunities to take advantage of
our improved capital structure and enhanced financial flexibility. These opportunities, for which we do not budget, include acquiring assets. We continue to evaluate our existing portfolio of undeveloped leases for exploration opportunities, and we
will consider purchasing interests in undeveloped leaseholds and participating in third party drilling opportunities to complement our existing asset base. In light of the recent regulatory actions taken with respect to leases in federal waters, it
is unclear when the federal government will offer additional offshore acreage for lease.

Capital expenditures on our
deepwater portfolio do not currently fit with our near-term strategy and may not fit with our longer term strategy, given the significant capital requirements and long lead times from initial investment to first production associated with deepwater
oil and natural gas exploration and development activities. We are currently evaluating our deepwater portfolio and may monetize or trade assets in that portfolio. As a result of the recent increased level of uncertainty surrounding the regulatory
environment and availability of equipment and resources to support deepwater development plans, we believe our ability to realize value from our deepwater lease positions in the near term is diminished.



16



---

##### Table of Contents

We expect our 2010 cash flows from operations to increase as compared to our operating cash
flows for the year ended December 31, 2009, primarily as a result of higher anticipated sales prices for oil and natural gas. We expect our cash used in investing activities for 2010 will increase as compared with our investing cash flows for
the year ended December 31, 2009, as a result of our planned increase in capital expenditures in 2010.

We have
experienced and may experience in the future substantial working capital deficits. Our working capital deficits have historically resulted from increased accounts payable and accrued expenses related to ongoing exploration and development costs,
which may be capitalized as noncurrent assets. At June 30, 2010, our working capital deficit was $24.8 million, compared to $16.9 million at December 31, 2009. However, as previously noted, we have $45 million undrawn and available under
the revolver component of our Amended Credit Facility.

We maintain restricted escrow funds in a trust for future plugging,
abandonment and other decommissioning costs at our East Bay field. The trust was originally funded with $15 million and, with accumulated interest, had increased to $16.7 million at December 31, 2008. We have made draws to date through July
2010 of $6.7 million, with $3.3 million drawn in 2010. We may draw from the trust upon the authorization, and subsequent completion, of qualifying abandonment activities at our East Bay field. As of July 30, 2010, we had $10.0 million remaining
in restricted escrow funds for decommissioning work in our East Bay field, $4.0 million of which will be available for draw upon authorization, and subsequent completion, of additional qualifying decommissioning activities as that work progresses.
The remaining $6.0 million 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.

Shortly following our emergence from Chapter 11 reorganization, we provided the Minerals Management Service, now
known as the Bureau of Ocean Energy Management, Regulation and Enforcement (the Bureau) with surety bonds in support of decommissioning obligations on certain federal leases in the Gulf of Mexico, and we resumed production from the
federal portion of the East Bay field. During April 2010, we regained supplemental waiver status, and we are no longer required to post these surety bonds. Restricted cash totaling $8.9 million held as collateral for these surety bonds and other
surety bonding obligations was released to us during the second quarter of 2010. We expect the cancellation of these surety bonds will reduce our surety bonding costs.

The Bureau and other regulatory bodies, including those regulating the decommissioning of our pipelines and facilities under the
jurisdiction of the state of Louisiana, may change their requirements or enforce requirements in a manner inconsistent with our expectations, which could materially increase the cost of such activities and/or accelerate the timing of cash
expenditures and could have a material adverse effect on our financial position, results of operations and cash flows. For important additional information regarding risks related to our regulatory environment, see the Risk Factors in Part II,
Item 1A of this Quarterly Report and in Part I, Item 1A of our 2009 Annual Report.

Analysis of Cash Flows
 Six Months Ended June 30, 2010

The following table sets forth our cash flows (in thousands):



|                                                      |  |                                              |         |   |                                                |   |         |  
|----------------------------------------------------- |  | -------------------------------------------- | ------- | - | ---------------------------------------------- | - | ------- | -
|                                                      |  | SuccessorCompanySix MonthsEndedJune 30, 2010 |         |   | PredecessorCompanySix MonthsEndedJune 30, 2009 |  
|Cash flows provided by operating activities           |  | $                                            | 67,488  |   |                                                | $ | 9,160   |  
|Cash flows used in investing activities               |  |                                              | (16,557 | ) |                                                |   | (27,574 | )
|Cash flows provided by (used in) financing activities |  |                                              | (49,488 | ) |                                                |   | 40,000  |  

The increase in our
2010 cash flows from operations primarily reflects the impact of the increase in oil and natural gas sales prices realized during the six months ended June 30, 2010 as compared to the six months ended June 30, 2009. Operating cash flows
for the six months ended June 30, 2010 also include cash payments totaling $15.8 million related to the redemption of our PIK Notes on June 28, 2010, which amount includes $9.7 million of interest for the period from September 21,
2009 through the redemption date and $6.1 million of original issue discount.

Net cash used in investing activities declined
in the six months ended June 30, 2010 as compared to the six months ended June 30, 2009 primarily due to a decrease in restricted cash. Our investing cash flows for the six months ended June 30, 2009, reflect, in part, that a higher
level of capital expenditure activities occurred in the fourth quarter of 2008 compared to the fourth quarter of 2009, which resulted in cash payments for prior quarter work during the quarter ended March 31, 2009 that were higher than those in
the quarter ended March 31, 2010.



17



---

##### Table of Contents

Net cash used in financing activities during the six months ended June 30, 2010
reflects the redemption of the PIK Notes and payments on the term loan component of our Credit Facility, partially offset by proceeds from the term loan component of our Amended Credit Facility. Net cash provided by financing activities during the
six months ended June 30, 2009 reflects increased utilization of the Predecessor Companys credit facility to fund working capital shortfalls caused by the decline in production and the precipitous decline in oil and natural gas sales
prices in 2009.

We have not paid any cash dividends in the past on our common stock. The covenants in certain debt
instruments to which we are a party, including the Amended Credit Facility, place certain restrictions and conditions on our ability to pay dividends. Any future cash dividends would depend on contractual limitations, future earnings, capital
requirements, our financial condition and other factors determined by our board of directors.

Cautionary Statement Concerning Forward
Looking Statements

This Quarterly Report contains certain forward-looking statements within the meaning of
Section 21E of the Securities Exchange Act of 1934, as amended (the Exchange Act). When used herein, the words will, would, should, likely, estimates, thinks,
strives, may, anticipates, expects, believes, intends, goals, plans, or projects and similar expressions are intended to identify
forward-looking statements, which are generally not historical in nature. While our management considers the expectations and assumptions to be reasonable when and as made, they are inherently subject to significant business, economic, competitive,
regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties relate to, among other matters, the following:



| |  |  | our ability to retain and motivate key executives and other necessary personnel;
| | - |  | --------------------------------------------------------------------------------



| |  |  | changes in general economic conditions;
| | - |  | ---------------------------------------



| |  |  | uncertainties in reserve and production estimates;
| | - |  | --------------------------------------------------



| |  |  | unanticipated recovery or production problems;
| | - |  | ----------------------------------------------



| |  |  | hurricane and other weather-related interference with business operations;
| | - |  | --------------------------------------------------------------------------



| |  |  | risks and hazards inherent in the production of oil and natural gas;
| | - |  | --------------------------------------------------------------------



| |  |  | the effects of delays in completion of, or shut-ins of, gas gathering systems, pipelines and processing facilities;
| | - |  | -------------------------------------------------------------------------------------------------------------------



| |  |  | oil and natural gas prices and competition;
| | - |  | -------------------------------------------



| |  |  | the impact of derivative positions;
| | - |  | -----------------------------------



| |  |  | production expense estimates;
| | - |  | -----------------------------



| |  |  | cash flow estimates;
| | - |  | --------------------



| |  |  | future financial performance;
| | - |  | -----------------------------



| |  |  | planned and unplanned capital expenditures;
| | - |  | -------------------------------------------



| |  |  | volatility in the financial and credit markets or in oil and natural gas prices;
| | - |  | --------------------------------------------------------------------------------



| |  |  | the impact of political and regulatory developments; and
| | - |  | --------------------------------------------------------



| |  |  | other matters that are discussed in our filings with the SEC.
| | - |  | -------------------------------------------------------------

These statements are based on current expectations and projections about future events and involve known and unknown risks,
uncertainties, and other factors that may cause actual results and performance to be materially different from any future results or performance expressed or implied by these forward-looking statements. Investors are cautioned that all such
statements involve risks and uncertainties. Our actual decisions, performance and results may differ materially. Important trends or factors that could cause actual results to differ materially from those in the forward-looking statements include,
but are not limited to, those described in the section Risk Factors in Part 1, Item 1A and elsewhere in our 2009 Annual Report, elsewhere in this Quarterly Report, and in our reports and registration statements filed from time to
time with the SEC, and other announcements we make from time to time.

Although we believe that the assumptions on which any
forward-looking statements are based in this Quarterly Report and other periodic reports filed by us are reasonable when and as made, no assurance can be given that such assumptions will prove correct. All forward-looking statements in this
Quarterly Report are expressly qualified in their entirety by the cautionary statements in this section and elsewhere in this Quarterly Report and we undertake no obligation to publicly update or revise any forward-looking statements, except as
required by applicable securities laws and regulations.



18



---

##### Table of Contents

|Item 3. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
|------- | ----------------------------------------------------------

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our
potential exposure to market risks. The term market risk refers to the risk of loss arising from adverse changes in oil and gas prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses,
but rather indicators of reasonably possible losses. This forward-looking information provides indicators of how we view our ongoing market-risk exposure.

Interest Rate Risk

We are exposed to changes in interest rates which affect the interest earned on our interest-bearing deposits and the interest paid on
borrowings under our Amended Credit Facility. Currently, we do not use interest rate derivative instruments to manage exposure to interest rate changes. At June 30, 2010, we had total indebtedness outstanding of $25.0 million, which bears
interest at floating rates and consists of borrowings outstanding under the Amended Credit Facility. At June 30, 2010, the weighted average interest rate under the Amended Credit Facility was approximately 7.5%. If market interest rates were to
average 1% higher in the third quarter of 2010, interest expense for the period on floating-rate debt would be expected to increase by approximately $51,000.

Commodity Price Risk

Our revenues, profitability and future growth depend substantially on prevailing prices for oil and natural gas. Prices also affect the
amount of cash flow available for capital expenditures and our ability to borrow and raise additional capital. The amount we can borrow under our Amended Credit Facility is subject to periodic redetermination based in part on changing expectations
of future prices. Lower prices may reduce the amount of oil and natural gas that we can economically produce. We currently sell all of our oil and natural gas production under price sensitive or market price contracts.

Historically, we have used commodity derivative instruments to manage commodity price risks associated with future oil and natural gas
production. As of June 30, 2010, the following derivative instruments were outstanding:

Oil Contracts



|                          |  |                           |  |              |      |                          |       |            |   |            |                            |  |              |  |                   |  |            |       |  |   |        
|------------------------- |  | ------------------------- |  | ------------ | ---- | ------------------------ | ----- | ---------- | - | ---------- | -------------------------- |  | ------------ |  | ----------------- |  | ---------- | ----- |  | - | -------
|                          |  | Fixed-Price Swaps         |  |              | Puts
|Remaining Contract Term   |  | Daily AverageVolume(Bbls) |  | Volume(Bbls) |      | AverageSwap Price($/Bbl) |       | Fair Value |   |            | Daily AverageVolume (Bbls) |  | Volume(Bbls) |  | FloorPrice($/Bbl) |  | Fair Value
|July 2010                 |  | 2,700                     |  | 83,700       |      | $                        | 68.84 |            | $ | (582,128   | )                          |  | 503          |  | 15,600            |  | $          | 60.00 |  | $ | 156    
|August 2010November 2010 |  | 625                       |  | 76,200       |      | $                        | 69.65 |            | $ | (547,115   | )                          |  | 1,673        |  | 204,150           |  | $          | 60.00 |  | $ | 179,840
|December 2010             |  | 1,200                     |  | 37,200       |      | $                        | 70.37 |            | $ | (274,768   | )                          |  | 1,302        |  | 40,350            |  | $          | 60.00 |  | $ | 70,935 
|January 2011July 2011    |  | 2,261                     |  | 479,250      |      | $                        | 71.13 |            | $ | (3,645,470 | )                          |  | 502          |  | 106,500           |  | $          | 60.00 |  | $ | 313,430
|August 2011November 2011 |  | 502                       |  | 61,200       |      | $                        | 72.18 |            | $ | (456,405   | )                          |  | 1,301        |  | 158,700           |  | $          | 60.00 |  | $ | 660,967
|December 2011             |  | 948                       |  | 29,400       |      | $                        | 72.64 |            | $ | (210,953   | )                          |  | 1,302        |  | 40,350            |  | $          | 60.00 |  | $ | 173,317

All of our
commodity derivative instruments are with one counterparty. For information regarding this counterparty and collateral requirements related to our derivative instruments, see Note 4, Indebtedness in the condensed consolidated financial
statements in Part 1, Item 1 of this Quarterly Report.



|Item 4. | CONTROLS AND PROCEDURES.
|------- | ------------------------

(a)
Quarterly Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures (as defined in
Rules 13a-15(e) and 15d-15(e) under the Exchange Act) are designed to ensure that information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified
in the SECs rules and forms. This information is also accumulated and communicated to management, including our principal executive officer and our principal financial officer, as appropriate, to allow timely decisions regarding required
disclosure. Our management, under the supervision and with the participation of our principal executive officer and principal financial officer, evaluated the effectiveness of the design and operation of our disclosure controls and procedures as of
the end of the most recent fiscal quarter reported on herein. Based on that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of June 30, 2010.

Because of their inherent limitations, disclosure controls and procedures may not prevent or detect misstatements.
Furthermore, projections of any evaluation of effectiveness to future periods are subject to the risk that such controls and procedures may become inadequate because of changes in conditions or deterioration in the degree of compliance with the
controls or procedures. Accordingly, even effective disclosure controls and procedures can provide only reasonable assurance of achieving their control objectives.



19



---

##### Table of Contents

(b) Changes in Internal Control Over Financial Reporting

There were no changes in our system of internal control over financial reporting during the three months ended June 30, 2010 that
have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II - OTHER
INFORMATION



|Item 1. | LEGAL PROCEEDINGS.
|------- | ------------------

For
information regarding legal proceedings, see the information in Note 7, Commitments and Contingencies in the condensed consolidated financial statements in Part I, Item 1 of this Quarterly Report.



|Item 1A. | RISK FACTORS.
|-------- | -------------

In
addition to the other information set forth in this Form 10-Q, you should carefully consider the factors discussed in Part I, Item 1A.  Risk Factors in our 2009 Annual Report that could materially affect our business, financial
condition or future results. The risks described in this Quarterly Report and in our 2009 Annual Report are not the only risks facing the Company. Additional risks and uncertainties not currently known to us, or that we currently deem to be
immaterial, also may materially adversely affect our business, financial condition and future results.

The following risk
factor is added to the risk factors included in our 2009 Annual Report:

The recent explosion and sinking of the Deepwater
Horizon drilling rig in the Gulf of Mexico and the resulting oil spill may significantly impact our risks.

The recent
explosion and sinking of the Deepwater Horizon drilling rig in the Gulf of Mexico and the resulting oil spill may significantly impact the risks we face, including but not limited to: potential increases in regulations in areas including health and
safety, environmental, permitting, taxation and equipment specifications; increased difficulty in obtaining permits to drill offshore wells; higher royalty rates; higher insurance costs or the unavailability of insurance on commercially acceptable
terms; higher financial responsibility requirements or financial responsibility requirements that are beyond our capacity; decreased access to equipment, personnel and infrastructure; and less favorable investor perception of the risk related to
investing in the oil and natural gas exploration and production industry. Any of these factors could have a material adverse effect on our business, financial position or results of operations and cash flows, and our ability to execute our
business plans.

The following risk factor from our 2009 Annual Report is revised:

Even though we have successfully entered into the Credit Facility, as amended, and emerged from our Chapter 11 reorganization, we will
continue to have substantial capital needs that we may not be able to satisfy in the future.

Like other oil and natural
gas exploration and production companies, our business has substantial capital requirements. In order to provide us with access to capital immediately following our emergence from our Chapter 11 reorganization, we entered into the Credit Facility,
which we amended in June 2010, and issued the PIK Notes, which we redeemed in June 2010, and we intend to finance our capital expenditures primarily through cash flow from operations. Because our cash flows are subject to a range of economic,
competitive and business risks, we may not be able to generate sufficient cash flow from operations to meet our debt payment obligations and to fund these capital requirements. Additionally, the amounts available to us under the Amended Credit
Facility may not be sufficient for our capital requirements not funded by initial cash flows, and we may not be able to access additional financing resources for a variety of reasons, including restrictive covenants in the Amended Credit Facility
and the general lack of available capital due to the condition of the global credit markets. If we are unable to make scheduled payments on the Amended Credit Facility, or if our financing requirements are not met by the Amended Credit Facility and
we are unable to access sources of additional financing on terms we find acceptable, our business, operations, financial condition and cash flows will be negatively impacted.



|Item 2. | UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.
|------- | ------------------------------------------------------------

None



|Item 3. | DEFAULTS UPON SENIOR SECURITIES.
|------- | --------------------------------

None



|Item 5. | OTHER INFORMATION.
|------- | ------------------

None



20



---

##### Table of Contents

|Item 6. | EXHIBITS.
|------- | ---------

The exhibits
marked with the cross symbol () are management contracts or compensatory plans or arrangements filed pursuant to Item 601(b)(10)(iii) of Regulation S-K. We have not filed with this Quarterly Report copies of the instruments defining
rights of all holders of the long-term debt of us and our consolidated subsidiaries based upon the exception set forth in Item 601(b)(4)(iii)(A) of Regulation S-K. Copies of such instruments will be furnished to the SEC upon request.



|        |  |                                                                                                                                                                                    |  |                          |  |           |  |         |  |             |  |                 
|------- |  | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ------------------------ |  | --------- |  | ------- |  | ----------- |  | ----------------
|Exhibit |  |                                                                                                                                                                                    |  | Incorporated byReference |  | SEC File  |  |         |  |             |  | Filed/
Furnished
|Number  |  | Exhibit Description                                                                                                                                                                |  | Form                     |  | Number    |  | Exhibit |  | Filing Date |  | Herewith        
|        |  |                                                                                                                                                                                    |  |                          |  |          
|2.0     |  | Second Amended Joint Plan of Reorganization of Energy Partners, Ltd. and certain of its Subsidiaries Under Chapter 11 of the Bankruptcy Code, as Modified as of September 16,
2009 |  | 10-Q                     |  | 001-16179 |  | 2.0     |  | 5/6/2010    |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|3.1     |  | Amended and Restated Certificate of Incorporation of Energy Partners, Ltd. dated as of September 21, 2009                                                                          |  | 8-K/A                    |  | 001-16179 |  | 3.1     |  | 9/21/2009   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|3.2     |  | Second Amended and Restated Bylaws of Energy Partners, Ltd.                                                                                                                        |  | 8-K/A                    |  | 001-16179 |  | 3.2     |  | 9/21/2009   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|4.1     |  | Notice of Redemption by Energy Partners, Ltd., as Issuer, and the Guarantors named therein, to The Bank of New York Mellon Trust Company, N.A., as Trustee, dated June 16, 2010    |  | 8-K                      |  | 001-16179 |  | 99.1    |  | 6/17/2010   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.1   |  | Offer Letter to Jonathan S. Gross, accepted on May 25, 2010                                                                                                                        |  | 8-K                      |  | 001-16179 |  | 10.1    |  | 6/4/2010    |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.2   |  | Fifth Amendment to the Energy Partners, Ltd. Change of Control Severance Plan                                                                                                      |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.3   |  | First Amendment to Employment Agreement, dated as of April 12, 2010 between Energy Partners, Ltd. and Gary Hanna                                                                   |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|31.1    |  | Certification of Principal Executive Officer of Energy Partners, Ltd. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002                                                    |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|31.2    |  | Certification of Principal Financial Officer of Energy Partners, Ltd. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002                                                    |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|32.1    |  | Section 1350 Certification of Principal Executive Officer of Energy Partners, Ltd. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002                                       |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|32.2    |  | Section 1350 Certification of Principal Financial Officer of Energy Partners, Ltd. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002                                       |  |                          |  |           |  |         |  |             |  | X               



21



---

##### Table of Contents

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned thereunto duly authorized.



|                     |  |  |  |                       |  |                                      
|-------------------- |  |  |  | --------------------- |  | -------------------------------------
|                     |  |  |  | ENERGY PARTNERS, LTD.
|                     |  |  | 
|Date: August 5, 2010 |  |  |  | By:                   |  | /s/ Gary C. Hanna                    
|                     |  |  |  |                       |  | Gary C. Hanna Chief Executive
Officer



22



---

##### Table of Contents

INDEX TO EXHIBITS

The exhibits marked with the cross symbol () are management contracts or compensatory plans or arrangements filed pursuant to
Item 601(b)(10)(iii) of Regulation S-K. We have not filed with this Quarterly Report copies of the instruments defining rights of all holders of the long-term debt of us and our consolidated subsidiaries based upon the exception set forth
in Item 601(b)(4)(iii)(A) of Regulation S-K. Copies of such instruments will be furnished to the SEC upon request.



|        |  |                                                                                                                                                                                    |  |                          |  |           |  |         |  |             |  |                 
|------- |  | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ------------------------ |  | --------- |  | ------- |  | ----------- |  | ----------------
|Exhibit |  |                                                                                                                                                                                    |  | Incorporated byReference |  | SEC File  |  |         |  |             |  | Filed/
Furnished
|Number  |  | Exhibit Description                                                                                                                                                                |  | Form                     |  | Number    |  | Exhibit |  | Filing Date |  | Herewith        
|        |  |                                                                                                                                                                                    |  |                          |  |          
|2.0     |  | Second Amended Joint Plan of Reorganization of Energy Partners, Ltd. and certain of its Subsidiaries Under Chapter 11 of the Bankruptcy Code, as Modified as of September 16,
2009 |  | 10-Q                     |  | 001-16179 |  | 2.0     |  | 5/6/2010    |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|3.1     |  | Amended and Restated Certificate of Incorporation of Energy Partners, Ltd. dated as of September 21, 2009                                                                          |  | 8-K/A                    |  | 001-16179 |  | 3.1     |  | 9/21/2009   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|3.2     |  | Second Amended and Restated Bylaws of Energy Partners, Ltd.                                                                                                                        |  | 8-K/A                    |  | 001-16179 |  | 3.2     |  | 9/21/2009   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|4.1     |  | Notice of Redemption by Energy Partners, Ltd., as Issuer, and the Guarantors named therein, to The Bank of New York Mellon Trust Company, N.A., as Trustee, dated June 16, 2010    |  | 8-K                      |  | 001-16179 |  | 99.1    |  | 6/17/2010   |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.1   |  | Offer Letter to Jonathan S. Gross, accepted on May 25, 2010                                                                                                                        |  | 8-K                      |  | 001-16179 |  | 10.1    |  | 6/4/2010    |  |                 
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.2   |  | Fifth Amendment to the Energy Partners, Ltd. Change of Control Severance Plan                                                                                                      |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|10.3   |  | First Amendment to Employment Agreement, dated as of April 12, 2010 between Energy Partners, Ltd. and Gary Hanna                                                                   |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|31.1    |  | Certification of Principal Executive Officer of Energy Partners, Ltd. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002                                                    |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|31.2    |  | Certification of Principal Financial Officer of Energy Partners, Ltd. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002                                                    |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|32.1    |  | Section 1350 Certification of Principal Executive Officer of Energy Partners, Ltd. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002                                       |  |                          |  |           |  |         |  |             |  | X               
|        |  |                                                                                                                                                                                    |  |                          |  |          
|32.2    |  | Section 1350 Certification of Principal Financial Officer of Energy Partners, Ltd. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002                                       |  |                          |  |           |  |         |  |             |  | X               



23