Epl Oil & Gas 10-KT 24 Sep 14 2014 FY Annual report (with FYE transition) Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	1 Months Ended
	Jun. 30, 2014
Document And Entity Information [Abstract]	'
Entity Registrant Name	'EPL OIL & GAS, INC.
Entity Central Index Key	'0000750199
Document Type	'10-K
Document Period End Date	30-Jun-14
Amendment Flag	'false
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'FY
Current Fiscal Year End Date	'--06-30
Entity Filer Category	'Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0
Entity Public Float	$0
Entity Well-known Seasoned Issuer	'Yes
Entity Voluntary Filers	'No
Entity Current Reporting Status	'Yes
Trading Symbol	'EPL

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2012

Jun. 30, 2014

Jun. 03, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

In Thousands, unless otherwise specified

Successor Company [Member]

Successor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Current assets:

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

$5,601

$200,050

$8,812

$3,885

$1,521

$5,601

$200,050

$200,050

$8,812

$1,521

$80,128

$33,553

Trade accounts receivable - net

'

'

'

'

'

72,301

93,007

91,813

70,707

67,991

'

'

Fair value of commodity derivative instruments

'

'

501

'

3,302

'

'

'

501

3,302

'

'

Deferred tax asset

24,587

'

8,949

'

3,322

24,587

24,587

8,405

8,949

3,322

'

'

Prepaid expenses

'

'

'

'

'

26,521

9,809

9,729

6,868

9,873

'

'

Total current assets

'

'

'

'

'

129,010

327,453

309,997

95,837

86,009

'

'

Property and equipment, under the full cost method of accounting, including $908.5 million of unevaluated properties not being amortized at June 30, 2014 and at cost under the successful efforts method of accounting at December 31, 2013 and 2012, net of accumulated depreciation, depletion and amortization

3,205,187

'

1,736,431

'

1,598,067

3,205,187

2,941,892

1,969,382

1,736,431

1,598,067

'

'

Deposit for Nexen Acquisition

'

'

'

'

'

'

'

'

7,040

'

'

'

Goodwill

'

'

'

'

'

327,235

327,235

'

'

'

'

'

Restricted cash

'

'

'

'

'

6,023

6,023

6,023

6,023

6,023

'

'

Fair value of commodity derivative instruments

'

'

238

'

211

'

27

27

238

211

'

'

Deferred financing costs - net of accumulated amortization of $5,549 and $2,596 at December 31, 2013 and 2012, respectively

'

'

'

'

'

'

'

9,002

10,106

12,386

'

'

Other assets

'

'

'

'

'

317

1,175

1,175

2,156

2,931

'

'

Total Assets

'

'

'

'

'

3,667,772

3,603,805

2,295,606

1,857,831

1,705,627

'

'

Current liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable

'

'

'

'

'

90,923

61,938

61,938

59,431

34,772

'

'

Due to EGC

'

'

'

'

'

4,960

'

'

'

'

'

'

Accrued expenses

'

'

'

'

'

161,518

230,086

230,086

131,125

117,372

'

'

Asset retirement obligations

39,831

39,859

51,601

'

30,179

39,831

43,617

39,859

51,601

30,179

'

'

Fair value of commodity derivative instruments

26,440

'

29,636

'

10,026

26,440

22,625

22,625

29,636

10,026

'

'

Total current liabilities

'

'

'

'

'

323,672

358,266

354,508

271,793

192,349

'

'

Long-term debt

1,025,566

'

627,355

'

689,911

1,025,566

1,026,407

973,440

627,355

689,911

'

'

Asset retirement obligations

232,864

220,302

203,849

'

204,931

232,864

229,755

220,302

203,849

204,931

'

'

Deferred tax liabilities

483,798

'

122,812

'

67,694

483,798

483,591

126,764

122,812

67,694

'

'

Fair value of commodity derivative instruments

2,140

'

2,136

'

3,637

2,140

1,439

1,439

2,136

3,637

'

'

Other

'

'

'

'

'

6

6

803

673

1,132

'

'

Total Liabilities

'

'

'

'

'

2,068,046

2,099,464

1,677,256

1,228,618

1,159,654

'

'

Commitments and contingencies (Note 14)

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' equity:

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, par value $0.001 per share. Authorized 1,000,000 shares; no shares issued and outstanding at June 30, 2014 and December 31, 2013 and 2012

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value $0.001 per share. Authorized 75,000,000 shares; shares issued: 1,000 at June 30, 2014 and 40,970,137 and 40,601,887 at December 31, 2013 and 2012, respectively; 1,000 shares outstanding at June 30, 2014 and 39,097,394 and 39,103,203 at December 31, 2013 and 2012, respectively

'

'

'

'

'

'

'

41

41

40

'

'

Additional paid-in capital

'

'

'

'

'

1,599,341

1,504,341

538,844

519,114

510,469

'

'

Accumulated other comprehensive income

'

'

'

'

'

-6,252

'

'

'

'

'

'

Treasury stock, at cost, no shares at June 30, 2014 and 1,872,743 and 1,498,684 shares at December 31, 2013 and 2012, respectively

'

'

'

'

'

'

'

-38,794

-31,157

-20,477

'

'

Retained earnings

'

'

'

'

'

6,637

'

118,259

141,215

55,941

'

'

Total stockholders' equity

'

'

'

'

'

1,599,726

1,504,341

618,350

629,213

545,973

491,045

473,116

Total liabilities and stockholders' equity

'

'

'

'

'

$3,667,772

$3,603,805

$2,295,606

$1,857,831

$1,705,627

'

'

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified
Consolidated Balance Sheets [Abstract]	'	'	'
Unevaluated properties	$908,483	$39,191	$36,992
Accumulated amortization, deferred financing costs	'	$5,549	$2,596
Preferred stock, par value	$0.00	$0.00	$0.00
Preferred stock, shares authorized	1,000,000	1,000,000	1,000,000
Preferred stock, shares issued	0	0	0
Preferred stock, shares outstanding	0	0	0
Common stock, par value	$0.00	$0.00	$0.00
Common stock, shares authorized	75,000,000	75,000,000	75,000,000
Common stock, shares issued	1,000	40,970,137	40,601,887
Common stock, shares outstanding	1,000	39,097,394	39,103,203
Treasury stock, shares	0	1,872,743	1,498,684

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	1 Months Ended	5 Months Ended	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenue:	'	'	'	'	'
Total revenue	$60,143	$276,400	'	'	'
Costs and expenses:	'	'	'	'	'
Accretion of liability for asset retirement obligations	2,022	11,771	28,299	15,565	'
Total costs and expenses	46,309	'	'	'	'
Income from operations	13,834	23,563	'	'	'
Other income (expense):	'	'	'	'	'
Gain (loss) on derivative instruments	'	-19,420	-32,361	-13,305	-5,870
Income (loss) before income taxes	10,211	-18,461	'	'	'
Deferred income tax expense	-3,574	-4,495	-49,687	-29,900	-14,822
Net income (loss)	6,637	-22,956	85,274	58,810	26,611
Basic earnings (loss) per share	'	($0.59)	$2.18	$1.50	$0.66
Diluted earnings (loss) per share	'	($0.59)	$2.15	$1.50	$0.66
Weighted average common shares used in computing earnings (loss) per share:	'	'	'	'	'
Basic	'	38,730	38,730	38,885	39,946
Diluted	'	38,730	39,236	39,034	40,050
Successor Company [Member]	'	'	'	'	'
Revenue:	'	'	'	'	'
Oil and natural gas	59,811	'	'	'	'
Other	332	'	'	'	'
Total revenue	60,143	'	'	'	'
Costs and expenses:	'	'	'	'	'
Lease operating	17,746	'	'	'	'
Transportation	299	'	'	'	'
Exploration expenditures and dry hole costs	'	'	'	'	'
Impairments	'	'	'	'	'
Depreciation, depletion and amortization	22,775	'	'	'	'
Accretion of liability for asset retirement obligations	2,022	'	'	'	'
General and administrative	2,617	'	'	'	'
Taxes, other than on earnings	850	'	'	'	'
Gain on sale of assets	'	'	'	'	'
Other	'	'	'	'	'
Total costs and expenses	46,309	'	'	'	'
Income from operations	13,834	'	'	'	'
Other income (expense):	'	'	'	'	'
Interest income	4	'	'	'	'
Interest expense	-3,627	'	'	'	'
Gain (loss) on derivative instruments	'	'	'	'	'
Loss on early extinguishment of debt	'	'	'	'	'
Total other expense	-3,623	'	'	'	'
Income (loss) before income taxes	10,211	'	'	'	'
Deferred income tax expense	-3,574	'	'	'	'
Net income (loss)	6,637	'	'	'	'
Basic earnings (loss) per share	'	'	'	'	'
Diluted earnings (loss) per share	'	'	'	'	'
Weighted average common shares used in computing earnings (loss) per share:	'	'	'	'	'
Basic	'	'	'	'	'
Diluted	'	'	'	'	'
Predecessor Company [Member]	'	'	'	'	'
Revenue:	'	'	'	'	'
Oil and natural gas	'	274,772	688,743	422,529	348,207
Other	'	1,628	4,295	1,104	120
Total revenue	'	276,400	693,038	423,633	348,327
Costs and expenses:	'	'	'	'	'
Lease operating	'	72,302	165,841	94,850	70,281
Transportation	'	1,475	3,568	615	779
Exploration expenditures and dry hole costs	'	26,239	26,555	18,799	14,268
Impairments	'	61	2,937	8,883	32,466
Depreciation, depletion and amortization	'	85,127	200,359	113,581	104,624
Accretion of liability for asset retirement obligations	'	11,771	28,299	15,565	15,942
General and administrative	'	51,434	28,137	23,208	18,741
Taxes, other than on earnings	'	4,384	11,490	13,007	14,365
Gain on sale of assets	'	'	-28,681	'	'
Other	'	44	34,942	4,678	9,735
Total costs and expenses	'	252,837	473,447	293,186	281,201
Income from operations	'	23,563	219,591	130,447	67,126
Other income (expense):	'	'	'	'	'
Interest income	'	17	99	136	102
Interest expense	'	-22,621	-52,368	-28,568	-17,548
Gain (loss) on derivative instruments	'	-19,420	-32,361	-13,305	-5,870
Loss on early extinguishment of debt	'	'	'	'	-2,377
Total other expense	'	-42,024	-84,630	-41,737	-25,693
Income (loss) before income taxes	'	-18,461	134,961	88,710	41,433
Deferred income tax expense	'	-4,495	-49,687	-29,900	-14,822
Net income (loss)	'	($22,956)	$85,274	$58,810	$26,611
Basic earnings (loss) per share	'	($0.59)	$2.18	$1.50	$0.66
Diluted earnings (loss) per share	'	($0.59)	$2.15	$1.50	$0.66
Weighted average common shares used in computing earnings (loss) per share:	'	'	'	'	'
Basic	'	38,730	38,730	38,885	39,946
Diluted	'	38,730	39,236	39,034	40,050

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	1 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014
Consolidated Statements of Comprehensive Income [Abstract]	'
Net Income	$6,637
Crude Oil and Natural Gas Cash Flow Hedges	'
Unrealized change in fair value net of ineffective portion	-11,170
Effective portion reclassified to earnings during the period	1,551
Total Other Comprehensive Loss	-9,619
Income Tax Benefit	3,367
Net Other Comprehensive Loss	-6,252
Comprehensive Income	$385

Consolidated_Statement_of_Chan

Consolidated Statement of Changes in Stockholders' Equity (USD $)

Treasury Stock [Member]

Treasury Stock [Member]

Common Stock [Member]

Common Stock [Member]

Additional Paid-in Capital [Member]

Additional Paid-in Capital [Member]

Retained Earnings (Accumulated Deficit) [Member]

Retained Earnings (Accumulated Deficit) [Member]

Other ComprehensiveIcome (Loss) [Member]

Predecessor Company [Member]

Successor Company [Member]

Total

In Thousands, except Share data

Predecessor Company [Member]

Successor Company [Member]

Predecessor Company [Member]

Successor Company [Member]

Predecessor Company [Member]

Successor Company [Member]

Predecessor Company [Member]

Successor Company [Member]

Successor Company [Member]

Balance at Dec. 31, 2010

'

'

$40

'

$502,556

'

($29,480)

'

'

$473,116

'

'

Balance, shares at Dec. 31, 2010

'

'

40,092,000

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

26,611

'

'

26,611

'

26,611

Stock option and restricted share awards

'

'

'

'

2,509

'

'

'

'

2,509

'

'

Stock option and restricted share awards, shares

'

'

217,000

'

'

'

'

'

'

'

'

'

Exercise of stock options

'

'

'

'

119

'

'

'

'

119

'

'

Exercise of stock options, shares

'

'

13,000

'

'

'

'

'

'

'

'

'

Purchase of shares into treasury

-11,353

'

'

'

'

'

'

'

'

-11,353

'

'

Purchase of shares into treasury, shares

916,000

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock used for tax withholding

-8

'

'

'

'

'

'

'

'

-8

'

'

Restricted Stock used for tax withholding, shares

6,000

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

51

'

'

'

'

51

'

'

Other, shares

'

'

4,000

'

'

'

'

'

'

'

'

'

Balance at Dec. 31, 2011

-11,361

'

40

'

505,235

'

-2,869

'

'

491,045

'

'

Balance, shares at Dec. 31, 2011

922,000

'

40,326,000

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

58,810

'

'

58,810

'

58,810

Stock option and restricted share awards

'

'

'

'

4,717

'

'

'

'

4,717

'

'

Stock option and restricted share awards, shares

'

'

226,000

'

'

'

'

'

'

'

'

'

Exercise of stock options

'

'

'

'

441

'

'

'

'

441

'

'

Exercise of stock options, shares

'

'

48,000

'

'

'

'

'

'

'

'

'

Purchase of shares into treasury

-8,798

'

'

'

'

'

'

'

'

-8,798

'

'

Purchase of shares into treasury, shares

549,000

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock used for tax withholding

-318

'

'

'

'

'

'

'

'

-318

'

'

Restricted Stock used for tax withholding, shares

28,000

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

76

'

'

'

'

76

'

'

Other, shares

'

'

2,000

'

'

'

'

'

'

'

'

'

Balance at Dec. 31, 2012

-20,477

'

40

'

510,469

'

55,941

'

'

545,973

'

'

Balance, shares at Dec. 31, 2012

1,499,000

'

40,602,000

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

85,274

'

'

85,274

'

85,274

Stock option and restricted share awards

'

'

'

'

7,344

'

'

'

'

7,344

'

'

Stock option and restricted share awards, shares

2,000

'

258,000

'

'

'

'

'

'

'

'

'

Exercise of stock options

'

'

1

'

1,384

'

'

'

'

1,385

'

'

Exercise of stock options, shares

'

'

108,000

'

'

'

'

'

'

'

'

'

Purchase of shares into treasury

-9,640

'

'

'

'

'

'

'

'

-9,640

'

'

Purchase of shares into treasury, shares

334,000

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock used for tax withholding

-1,040

'

'

'

'

'

'

'

'

-1,040

'

'

Restricted Stock used for tax withholding, shares

38,000

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

-83

'

'

'

'

-83

'

'

Other, shares

'

'

2,000

'

'

'

'

'

'

'

'

'

Balance at Dec. 31, 2013

-31,157

'

41

'

519,114

'

141,215

'

'

629,213

'

'

Balance, shares at Dec. 31, 2013

1,873,000

'

40,970,000

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

-22,956

'

'

-22,956

'

-22,956

Stock option and restricted share awards

'

'

'

'

11,456

'

'

'

'

11,456

'

'

Stock option and restricted share awards, shares

'

'

162,000

'

'

'

'

'

'

'

'

'

Exercise of stock options

'

'

'

'

8,248

'

'

'

'

8,248

'

'

Restricted Stock used for tax withholding

-7,637

'

'

'

'

'

'

'

'

-7,637

'

'

Restricted Stock used for tax withholding, shares

208,000

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

26

'

'

'

'

26

'

'

Other, shares

'

'

1,000

'

'

'

'

'

'

'

'

'

Balance at Jun. 03, 2014

-38,794

'

41

'

538,844

'

118,259

'

'

618,350

1,504,341

'

Balance, shares at Jun. 03, 2014

2,081,000

'

41,133,000

'

'

'

'

'

'

'

'

'

Pushdown adjustments

'

38,794

'

-41

'

965,497

'

-118,259

'

'

885,991

'

Pushdown adjustments, shares

'

-2,081,000

'

-41,132,000

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

'

'

'

'

6,637

'

'

6,637

6,637

Capital contribution from EGC

'

'

'

'

'

95,000

'

'

'

'

95,000

'

Comprehensive income (loss)

'

'

'

'

'

'

'

'

-6,252

'

-6,252

-6,252

Balance at Jun. 30, 2014

'

'

'

'

'

$1,599,341

'

$6,637

($6,252)

'

$1,599,726

'

Balance, shares at Jun. 30, 2014

'

'

'

1,000

'

'

'

'

'

'

'

'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	1 Months Ended	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'	'	'
Net income (loss)	$6,637	($22,956)	$85,274	$58,810	$26,611
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'	'	'
Accretion of liability for asset retirement obligations	2,022	11,771	28,299	15,565	'
Deferred income taxes	3,574	4,495	49,687	29,900	14,822
Changes in operating assets and liabilities:	'	'	'	'	'
Net cash provided by operating activities	22,209	105,122	'	'	'
Cash flows provided by (used in) investing activities:	'	'	'	'	'
Net cash used in investing activities	-200,929	-258,714	'	'	'
Cash flows provided by (used in) financing activities:	'	'	'	'	'
Net cash provided by (used in) financing activities	-15,729	344,830	'	'	'
Net increase (decrease) in cash and cash equivalents	-194,449	191,238	'	'	'
Cash and cash equivalents at beginning of period	200,050	8,812	1,521	'	'
Cash and cash equivalents at end of period	5,601	200,050	8,812	1,521	'
Successor Company [Member]	'	'	'	'	'
Cash flows from operating activities:	'	'	'	'	'
Net income (loss)	6,637	'	'	'	'
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'	'	'
Depreciation, depletion and amortization	22,775	'	'	'	'
Accretion of liability for asset retirement obligations	2,022	'	'	'	'
Deferred income taxes	3,574	'	'	'	'
Impairments	'	'	'	'	'
Amortization of deferred financing costs and discount on debt	-841	'	'	'	'
Gain on sale of assets	'	'	'	'	'
Changes in operating assets and liabilities:	'	'	'	'	'
Trade accounts receivable	18,238	'	'	'	'
Prepaid expenses	2,415	'	'	'	'
Other assets	859	'	'	'	'
Accounts payable and accrued expenses	-29,683	'	'	'	'
Asset retirement obligation settlements	-3,787	'	'	'	'
Net cash provided by operating activities	22,209	'	'	'	'
Cash flows provided by (used in) investing activities:	'	'	'	'	'
Property acquisitions	-141,886	'	'	'	'
Exploration and development expenditures	-58,976	'	'	'	'
Other property and equipment additions	-67	'	'	'	'
Net cash used in investing activities	-200,929	'	'	'	'
Cash flows provided by (used in) financing activities:	'	'	'	'	'
Proceeds from indebtedness	475,000	'	'	'	'
Repayments of indebtedness	-475,000	'	'	'	'
Advances to EGC	-15,729	'	'	'	'
Net cash provided by (used in) financing activities	-15,729	'	'	'	'
Net increase (decrease) in cash and cash equivalents	-194,449	'	'	'	'
Cash and cash equivalents at beginning of period	200,050	'	'	'	'
Cash and cash equivalents at end of period	5,601	'	'	'	'
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION	'	'	'	'	'
Capital contribution from EGC	95,000	'	'	'	'
Interest	1,559	'	'	'	'
Predecessor Company [Member]	'	'	'	'	'
Cash flows from operating activities:	'	'	'	'	'
Net income (loss)	'	-22,956	85,274	58,810	26,611
Adjustments to reconcile net income (loss) to net cash provided by operating activities:	'	'	'	'	'
Depreciation, depletion and amortization	'	85,127	200,359	113,581	104,624
Accretion of liability for asset retirement obligations	'	11,771	28,299	15,565	15,942
Change in fair value of derivative instruments	'	-6,996	20,884	9,491	-11,475
Non-cash compensation	'	19,704	7,344	4,717	2,509
Deferred income taxes	'	4,495	49,687	29,900	14,822
Exploration expenditures	'	14,825	5,520	4,227	11,239
Impairments	'	61	2,937	8,883	32,466
Amortization of deferred financing costs and discount on debt	'	2,359	5,396	2,556	1,657
Gain on sale of assets	'	'	-28,681	'	'
Loss on early extinguisment of debt	'	'	'	'	2,377
Other	'	-573	27,235	2,448	6,984
Changes in operating assets and liabilities:	'	'	'	'	'
Trade accounts receivable	'	-21,106	-1,916	-33,547	-10,037
Other receivables	'	'	'	'	2,088
Prepaid expenses	'	-2,861	2,081	1,047	-7,623
Other assets	'	980	790	145	-1,215
Accounts payable and accrued expenses	'	52,932	35,658	31,477	12,650
Asset retirement obligation settlements	'	-32,640	-53,308	-35,429	-32,364
Other liabilities	'	'	'	'	-3
Net cash provided by operating activities	'	105,122	387,559	213,871	171,252
Cash flows provided by (used in) investing activities:	'	'	'	'	'
Decrease in restricted cash	'	'	'	'	2,466
Property acquisitions	'	-60,495	-27,560	-578,372	-235,486
Deposit for Nexen Acquisition	'	'	-7,040	'	'
Exploration and development expenditures	'	-197,968	-322,040	-184,850	-76,003
Other property and equipment additions	'	-251	-2,016	-1,743	-1,568
Proceeds from sale of assets	'	'	52,317	'	'
Net cash used in investing activities	'	-258,714	-306,339	-764,965	-310,591
Cash flows provided by (used in) financing activities:	'	'	'	'	'
Proceeds from indebtedness	'	345,000	'	509,313	203,794
Repayments of indebtedness	'	'	-65,000	-20,000	'
Deferred financing costs	'	-170	-674	-8,469	-6,646
Purchase of shares into treasury	'	'	-9,640	-8,798	-11,353
Exercise of stock options	'	'	1,385	441	119
Net cash provided by (used in) financing activities	'	344,830	-73,929	472,487	185,914
Net increase (decrease) in cash and cash equivalents	'	191,238	7,291	-78,607	46,575
Cash and cash equivalents at beginning of period	'	8,812	1,521	80,128	33,553
Cash and cash equivalents at end of period	'	200,050	8,812	1,521	80,128
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION	'	'	'	'	'
Interest	'	$23,185	$47,339	$21,129	$9,395

Organization_and_Summary_of_Si

Organization and Summary of Significant Accounting Policies	1 Months Ended
	Jun. 30, 2014
Organization and Summary of Significant Accounting Policies [Abstract]	'
Organization and Summary of Significant Accounting Policies	'
	(1)  Organization and Summary of Significant Accounting Policies
	EPL Oil & Gas, Inc. (referred to herein as “we,” “our,” “us,” “EPL” or “the Company”) was incorporated as a Delaware corporation on January 29, 1998 and is a wholly-owned subsidiary of Energy XXI Gulf Coast, Inc. (“EGC”), a Delaware corporation and indirect wholly-owned subsidiary of Energy XXI (Bermuda) Limited, an exempted company under the laws of Bermuda (“Energy XXI”). We operate as an independent oil and natural gas exploration and production company based in Houston, Texas and New Orleans, Louisiana.  Effective September 1, 2012, we changed our legal corporate name from “Energy Partners, Ltd.” to “EPL Oil & Gas, Inc.” through a short-form merger pursuant to Section 253 of the General Corporation Law of the State of Delaware.
	On June 3, 2014, Energy XXI, EGC, Clyde Merger Sub, Inc., a wholly owned subsidiary of EGC (“Merger Sub”), and EPL, completed the transactions contemplated by the Agreement and Plan of Merger, dated as of March 12, 2014 (as amended, the “Merger Agreement”), by and among Energy XXI, EGC, Merger Sub, and EPL, pursuant to which Merger Sub was merged with and into EPL with EPL continuing as the surviving corporation (the “Merger”).  Pursuant to the Merger Agreement, at the effective time of the Merger (the “Effective Time”), the issued and outstanding shares of EPL common stock, par value $0.001 per share (“EPL Common Stock”), were converted, in the aggregate, into the right to receive merger consideration (the “Merger Consideration”) consisting of approximately 65% in cash and 35% in shares of common stock of Energy XXI, par value $0.005 per share (“Energy XXI Common Stock”).  See Note 4, “Common Stock” for more information regarding the Merger Consideration.
	Our current operations are concentrated in the U.S. Gulf of Mexico shelf (the “GoM shelf”) focusing on state and federal waters offshore Louisiana, which we consider our core area. We have focused on acquiring and developing assets in this region, because the region is characterized by established exploitation, development and exploration opportunities in both productive horizons and deeper geologic formations.
	A summary of acquisition activity during 2014, 2013 and 2012 is as follows (purchase prices are before economic effective date adjustments):
		·	On June 3, 2014, we acquired from Energy XXI GOM, LLC, a Delaware limited liability company and wholly-owned subsidiary of Energy XXI (“Energy XXI GOM”), an asset package consisting of certain shallow water GoM shelf oil and natural gas interests in our South Pass 49 field located for $230 million;
		·	On January 15, 2014, we acquired 100% working interest of certain shallow-water central GoM shelf oil and natural gas assets comprised of five leases in the Eugene Island 258/259 field for $70.4 million;
		·	On September 26, 2013, we acquired an asset package consisting of certain GoM shelf oil and natural gas interests in the West Delta 29 field for $21.8 million;
		·	On October 31, 2012, we acquired from Hilcorp Energy GOM Holdings, LLC 100% of the membership interests of Hilcorp Energy GOM, LLC, which owned certain shallow water GoM shelf oil and natural gas interests for $550.0 million; and
		·	On May 15, 2012, we acquired an asset package consisting of certain shallow-water GoM shelf oil and natural gas interests in our South Timbalier 41 field for $32.4 million.
	In addition, on April 2, 2013, we sold certain shallow water GoM shelf oil and natural gas interests located within the non-operated Bay Marchand field for total consideration of $62.8 million. See Note 3, “Acquisitions and Disposition” for more information regarding these transactions.
	A summary of significant accounting policies followed in the preparation of the accompanying consolidated financial statements is set forth below.
	(a) Basis of Presentation
	The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of EPL and our wholly-owned subsidiaries. All significant intercompany accounts and transactions are eliminated in consolidation. Our interests in oil and natural gas exploration and production ventures and partnerships are proportionately consolidated.
	The Merger resulted in EPL becoming an indirect, wholly owned subsidiary of Energy XXI.  Therefore, in the preparation of our financial statements, we have applied “pushdown” accounting, based on guidance from the Securities and Exchange Commission (“SEC”).  Pushdown accounting refers to the use of the acquiring entity’s basis of accounting in the preparation of the acquired entity’s financial statements.  As a result, our separate financial statements reflect the new basis of accounting recorded by the Energy XXI upon acquisition.  As such, in accordance with GAAP, due to our new basis of accounting, our financial statements include a black line denoting that our financial statements covering periods prior to the date of the Merger are not comparable to our financial statements as of and subsequent to the date of the Merger.  References to the “Predecessor Company” refer to reporting dates of the Company through June 3, 2014, reflecting results of operations and cash flows of the Company prior to the Merger on our historical accounting basis; subsequent thereto, the Company is referred to as the “Successor Company,” reflecting the impact of pushdown accounting and the results of operations and cash flows of the Company subsequent to the Merger. See Note 2, “Pushdown Accounting” for more information regarding these transactions.
	Energy XXI follows the “full cost” method of accounting for its oil and gas producing activities, while we had historically followed the “successful efforts” method of accounting. Subsequent to the Merger, we converted our accounting method from successful efforts to the full cost method of accounting to be consistent with Energy XXI’s method of accounting pursuant to SEC guidance, which requires a reporting entity that follows the full cost method to apply that method to all of its operations and to the operations of its subsidiaries. Under GAAP, a change in accounting method is required to be applied retroactively in order to provide comparable historical period information to users of financial statements. However, due to the new basis of accounting established as a result of the Merger transaction and pushdown accounting, our financial statements are no longer comparable to those of prior periods and we have applied the full cost method of accounting on a prospective basis from the date of the Merger.
	Energy XXI has a fiscal year end of June 30, while we historically had a fiscal year end of December 31. Subsequent to the Merger, we changed our year end to June 30 to be consistent with Energy XXI.  Therefore, these financial statements include audited statements of operations, cash flows and stockholders’ equity using the successful efforts method of accounting applied to our historical basis in our assets and liabilities for the five months and three days ended June 3, 2014 and audited statements of operations, cash flows and stockholders’ equity using the full cost method of accounting applied to EPL’s new basis in its assets and liabilities established in the Merger transaction for the twenty-seven days ended June 30, 2014, with a black line between the periods denoting that they are not comparable.
	(b) Oil and Natural Gas Property and Equipment
	Prior to the Merger, we used the successful efforts method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and complete exploratory wells that find proved reserves, and to drill and complete development wells are capitalized. Exploratory drilling costs were initially capitalized, but charged to expense if and when the well is determined not to have found reserves in commercial quantities. We may have capitalized exploratory well costs beyond one year if (a) we found a sufficient quantity of reserves to justify its completion as a producing well and (b) we were making sufficient progress assessing the reserves and the economic and operating viability of the project; otherwise, these costs were expensed. Geological and geophysical costs were charged to expense as incurred.
	Leasehold acquisition costs were capitalized as unproved properties. If proved reserves were discovered on undeveloped leases, the related leasehold costs were transferred to proved properties and amortized using the units of production method. For individual unevaluated properties with capitalized costs below a threshold amount, we allocated capitalized costs to earnings generally over the primary lease terms. Properties that were subject to amortization and those with capitalized costs greater than the threshold amount were assessed for impairment periodically. Capitalized costs of producing oil and natural gas properties were depreciated and depleted by the units-of-production method.
	We evaluated our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicated that the carrying values may not have been recoverable. The need to test a property for impairment was based on several factors, including a significant reduction in sales prices for oil and/or natural gas, unfavorable adjustments to reserve volumes, actual operating and development costs in excess of expected amounts, changes in estimates of future operating and capital expenditure requirements, or other changes to contracts, environmental regulations or tax laws. The calculation was performed on a field-by-field basis, utilizing our current estimates of future revenues and operating expenses. In the event net undiscounted cash flow was less than the carrying value, an impairment loss was recorded based on the present value of expected future net cash flows over the economic lives of the reserves.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion, depreciation and amortization were eliminated from the property accounts, along with the related asset retirement obligations, unless retained by us, and the resulting gain or loss was recognized in earnings.
	As described above, subsequent to the Merger, we adopted the full cost method of accounting for exploration and development activities. Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.
	Oil and natural gas properties include costs that are excluded from costs being depleted or amortized. Costs excluded from depletion or amortization represent investments in unevaluated properties and include non-producing leasehold, geological and geophysical costs associated with leasehold or drilling interests and exploration drilling costs. We exclude these costs until the property has been evaluated.  We also allocate a portion of our acquisition costs to unevaluated properties based on fair value.  Costs are transferred to the full cost pool as the properties are evaluated or over the life of the reservoir.
	We evaluate the impairment of our evaluated oil and natural gas properties through the use of a ceiling test as prescribed by SEC Regulation S-X Rule 4-10. Future production volumes from oil and natural gas properties are a significant factor in determining the full cost ceiling limitation of capitalized costs. There are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves. Oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be precisely measured. Such cost estimates related to future development costs of proved oil and natural gas reserves could be subject to revisions due to changes in regulatory requirements, technological advances and other factors which are difficult to predict.
	(c) Other Property and Equipment
	Other property and equipment include buildings, data processing and telecommunications equipment, office furniture and equipment, vehicle and leasehold improvements and other fixed assets.  These items are recorded at cost and are depreciated using the straight-line method based on expected lives of the individual assets or group of assets, which ranges from three to five years.  Repairs and maintenance costs are expensed in the period incurred.
	(d) Asset Retirement Obligations
	Our investment in oil and natural gas properties includes an estimate of the future cost associated with dismantlement, abandonment and restoration of our properties. The present value of the future costs are added to the capitalized cost of our oil and natural gas properties and recorded as a long-term or current liability. The capitalized cost is included in oil and natural gas properties cost that are depleted over the life of the assets. The estimation of future costs associated with dismantlement, abandonment and restoration requires the use of estimated costs in future periods that, in some cases, will not be incurred until a substantial number of years in the future. Such cost estimates could be subject to revisions in subsequent years due to changes in regulatory requirements, technological advances and other factors which may be difficult to predict.
	(e)  Income Taxes
	We account for income taxes under the asset and liability method, which requires that we recognize deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis amounts. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We recognize the effect on deferred tax assets and liabilities of a change in the tax rates in income in the period that includes the enactment date.
	We follow the provisions of Financial Accounting Standards Board Accounting Standards Codification (“ASC”) Topic 740, “Income Taxes,” which apply to the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements and prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These provisions also contain guidance on de-recognition, classification, interest and penalties. Interest, if any, is classified as a component of interest expense, and statutory penalties, if any, are classified as a component of general and administrative expense.
	(f) Deferred Financing Costs
	We defer costs incurred to obtain debt financing and then amortize such costs as additional interest expense over the maturity period of the related debt using the effective interest rate method.
	(g) Earnings Per Share
	Basic earnings per share is computed by dividing income or loss available to common stockholders by the weighted average number of common shares outstanding during each period. According to GAAP, we have determined that our unvested restricted share awards, which contain non-forfeitable rights to dividends, are participating securities and should be included in the computation of earnings per share pursuant to the “two-class” method. The “two-class” method allocates undistributed earnings between common shares and participating securities. The diluted earnings per share calculation under the “two-class” method also includes the effect, if dilutive, of potential common shares associated with stock option awards outstanding during each period. The dilutive effect of stock options is determined using the treasury stock method.
	(h) Revenue Recognition
	We record revenues from the sales of oil and natural gas when the product is delivered at a determinable price, title has transferred and collectability is reasonably assured. When we have an interest with other producers in properties from which natural gas is produced, we use the entitlement method for recording natural gas sales revenue. Under this method of accounting, revenue is recorded based on our net revenue interest in production. Deliveries of natural gas in excess of our revenue interest are recorded as liabilities and under-deliveries are recorded as receivables. We had natural gas imbalance liabilities of $2.0 million, $2.0 million and $1.7 million at June 30, 2014 and December 31, 2013 and 2012, respectively. We had natural gas imbalance receivables of $0.2 million, $1.9 million and $0.8 million at June 30, 2014 and December 31, 2013 and 2012, respectively.
	(i) Cash and Cash Equivalents
	We include in cash and cash equivalents our highly-liquid investments with original maturities of three months or less. At December 31, 2013 and 2012, cash and cash equivalents includes investments in overnight interest-bearing deposits of $7.3 million and $2.3 million, respectively. These amounts are reduced by overdraft balances on other operating accounts with legal right of offset in the same banking institution to arrive at the cash and cash equivalent balances reported in our consolidated balance sheets.
		(j)	Derivative Activities
	Derivative instruments, including certain derivative instruments embedded in other contracts, are recorded at fair value and included as either assets or liabilities in the consolidated balance sheets. The accounting for changes in fair value depends on the intended use of the derivative and the resulting designation, which is established at the inception of the derivative. Prior to the Merger, we did not elect to designate derivative instruments as hedges. Gains and losses resulting from changes in the fair value of derivative instruments were recorded in other income (expense). Gains and losses related to contract settlements were also recorded in other income (expense).
	Subsequent to the Merger, gains or losses resulting from transactions designated as cash flow hedges, recorded at market value, are deferred and recorded, net of the related tax impact, in Accumulated Other Comprehensive Income (“AOCI”) as appropriate, until recognized as operating income in our consolidated statement of operations as the physical production hedged by the contracts is delivered. Instruments not qualifying for hedge accounting treatment are recorded in the consolidated balance sheets and changes in fair value are recognized directly in earnings.
	The net cash flows related to any recognized gains or losses associated with cash flow hedges are reported as oil and natural gas revenue and presented in cash flow from operations. If a hedge is terminated prior to expected maturity, gains or losses are deferred and included in income in the same period as the physical production hedged by the contract is delivered.
	(k) Share-Based Compensation
	We recognize share-based compensation expense based on the estimated grant-date fair value of all share-based awards, net of an estimated forfeiture rate, over the requisite service period of the awards, which is generally equivalent to the vesting term. We record share-based compensation expense only for those awards expected to vest. We periodically revise our estimated forfeiture rate if actual forfeitures differ from our estimates.  Compensation expense for liability awards is based on the fair value of the vested award at the end of each reporting period.
	We are required to report excess tax benefits from the exercise of stock options as financing cash flows. For the period from January 1, 2014 through June 3, 2014 and the years ended December 31, 2013 and 2012, no excess tax benefits were reported in the statement of cash flows as we were in a net operating loss carryforward position. See Note 12, “Income Taxes,” for additional disclosures.
	(l) Accounts Receivable and Allowance for Doubtful Accounts
	Accounts receivable are stated at historical carrying amount net of allowance for doubtful accounts.  We establish provisions for losses on accounts receivable if it is determined that collection of all or a part of an outstanding balance is not probable.  Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method.   As of June 30, 2014, no allowance for doubtful accounts was necessary.  As of December 31, 2013, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2013.  As of December 31, 2012, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2012.
	(m) Accrued Expenses
	As of June 30, 2014, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $127.6 million, other accrued expenses of $18.1 million and interest payable of approximately $15.8 million. As of December 31, 2013, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $107.8 million, other accrued expenses of $7.5 million and interest payable of approximately $15.8 million. As of December 31, 2012, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $ 84.9 million, other accrued expenses of $ 16.3 million and interest payable of approximately $ 16.2 million.
	(n) Goodwill
	We recorded goodwill during 2014 as a result of pushdown accounting in conjunction with the Merger.  Goodwill has an indefinite useful life and is not amortized, but rather is tested for impairment at least annually during the fiscal third quarter, unless events occur or circumstances change between annual tests that would more likely than not reduce the fair value of a related reporting unit below its carrying value. Impairment occurs when the carrying amount of goodwill exceeds its implied fair value. Events affecting crude oil and natural gas prices may cause a decrease in the fair value of the reporting unit, and we could have an impairment of goodwill in future periods.
	(o) Use of Estimates
	The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We use historical experience and various other assumptions that are believed to be reasonable under the circumstances to form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Our actual results may differ from these estimates and assumptions used in preparation of our financial statements. Significant estimates with regard to these financial statements and related unaudited disclosures include the estimate of proved oil and natural gas reserve quantities and the related present value of estimated future net cash flows therefrom disclosed in Note 18, "Supplementary Oil and Natural Gas Disclosures”.
	(p) New Accounting Pronouncements
	In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (ASU 2014-09). ASU 2014-09 provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and will supersede most current revenue recognition guidance. The standard is effective for public entities for annual and interim periods beginning after December 15, 2016. Early adoption is not permitted. We are currently evaluating the provisions of ASU 2014-09 and assessing the impact, if any, it may have on our financial position, results of operations or cash flows.
	In August 2014, the FASB issued Accounting Standards Update No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15).  ASU 2014-15 requires management to assess an entity’s ability to continue as a going concern, and to provide related footnote disclosures in certain circumstances.  The standard is effective for public entities for annual and interim periods beginning after December 15, 2016, with early adoption permitted. We are currently evaluating the provisions of ASU 2014-15 and assessing the impact, if any, it may have on our financial position, results of operations or cash flows.

Pushdown_Accounting

Pushdown Accounting	1 Months Ended
	Jun. 30, 2014
Pushdown Accounting [Abstract]	'
Pushdown Accounting	'
	(2) Pushdown Accounting
	As described in Note 1, the Merger resulted in EPL becoming an indirect, wholly owned subsidiary of Energy XXI.  Therefore, we have applied “pushdown” accounting, based on guidance from the SEC.  The following table reflects the impact on our condensed consolidated balance sheet of the pushdown accounting adjustments required to reflect the fair value of our assets acquired and liabilities assumed by Energy XXI in the Merger:
		PREDECESSOR				SUCCESSOR
		COMPANY				COMPANY
		June 3,		PUSHDOWN		June 3,
		2014		ADJUSTMENTS		2014
	ASSETS
	Current assets:
	Cash and cash equivalents	$	200,050	$	-	$	200,050
	Trade accounts receivable - net		91,813		1,194		93,007
	Deferred tax asset		8,405		16,182		24,587
	Prepaid expenses		9,729		80		9,809
	Total current assets		309,997		17,456		327,453
	Property and equipment, net of accumulated depreciation, depletion and amortization		1,969,382		972,510		2,941,892
	Goodwill		-		327,235		327,235
	Restricted cash		6,023		-		6,023
	Fair value of commodity derivative instruments		27		-		27
	Deferred financing costs		9,002		-9,002		-
	Other assets		1,175		-		1,175
	Total assets	$	2,295,606	$	1,308,199	$	3,603,805
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	61,938	$	-	$	61,938
	Accrued expenses		230,086		-		230,086
	Asset retirement obligations		39,859		3,758		43,617
	Fair value of commodity derivative instruments		22,625		-		22,625
	Total current liabilities		354,508		3,758		358,266
	Long-term debt		973,440		52,967		1,026,407
	Asset retirement obligations		220,302		9,453		229,755
	Deferred tax liabilities		126,764		356,827		483,591
	Fair value of commodity derivative instruments		1,439		-		1,439
	Other		803		-797		6
	Total liabilities		1,677,256		422,208		2,099,464
	Commitments and contingencies
	Stockholders’ equity:
	Preferred stock, par value $0.001 per share.		-		-		-
	Common stock, par value $0.001 per share.		41		-41		-
	Additional paid-in capital		538,844		965,497		1,504,341
	Treasury stock, at cost		-38,794		38,794		-
	Retained earnings		118,259		-118,259		-
	Total stockholders’ equity		618,350		885,991		1,504,341
	Total liabilities and stockholders' equity	$	2,295,606	$	1,308,199	$	3,603,805
	In accordance with the acquisition method of accounting, the purchase price established in the Merger has been allocated to the assets acquired and liabilities assumed based on their estimated fair values on the acquisition date. The fair value estimates were based on, but not limited to quoted market prices, where available; expected future cash flows based on estimated reserve quantities; estimated costs to produce and develop reserves; current replacement cost for similar capacity for certain fixed assets; market rate assumptions for contractual obligations; appropriate discount rates and growth rates; and crude oil and natural gas forward prices. Deferred income taxes have been recognized based on the estimated fair value adjustments to net assets using a 37 percent tax rate, which reflected the 35 percent federal statutory rate and a 2 percent weighted-average of the applicable statutory state tax rates (net of federal benefit). The excess of the total consideration over the estimated fair value of the amounts initially assigned to the identifiable assets acquired and liabilities assumed has been recorded as goodwill. Goodwill recorded in connection with the acquisition is not deductible for income tax purposes.
	The final valuation of assets acquired and liabilities assumed is not complete and the net adjustments to those values may result in changes to goodwill and other carrying amounts initially assigned to the assets and liabilities based on the preliminary fair value analysis. The principal remaining items to be valued are tax assets and liabilities, and any related valuation allowances, which will be finalized in connection with the filing of related tax returns.
	The fair value measurements of the oil and natural gas properties and the asset retirement obligations included in other long-term liabilities were based, in part, on significant inputs not observable in the market and thus represent Level 3 measurements.  The fair value measurement of long-term debt was based on prices obtained from a readily available pricing source and thus represents a Level 2 measurement.
	Goodwill primarily resulted from the requirement to recognize deferred taxes on the difference between the fair value and the historical tax basis of the acquired assets. At June 30, 2014, we conducted a qualitative goodwill impairment assessment by examining relevant events and circumstances that could have a negative impact on our goodwill, such as macroeconomic conditions, industry and market conditions, cost factors that have a negative effect on earnings and cash flows, overall financial performance, dispositions and acquisitions, and any other relevant events or circumstances. After assessing the relevant events and circumstances for the qualitative impairment assessment, we determined that performing a quantitative goodwill impairment test was unnecessary, and no goodwill impairment was recognized.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	1 Months Ended
	Jun. 30, 2014
Acquisitions and Dispositions [Abstract]	'
Acquisitions and Dispositions	'
	(3) Acquisitions and Dispositions
	The South Pass 49 Acquisition
	On June 3, 2014 we acquired from Energy XXI GOM an asset package consisting of certain shallow-water GoM shelf oil and natural gas interests in our South Pass 49 field (the “SP49 Interests”) for $230.0 million, subject to customary adjustments to reflect an economic effective date of June 1, 2014 (the “SP49 Acquisition). We estimate that the proved reserves as of the June 1, 2014 economic effective date totaled approximately 11.3 Mmboe, of which 74% were oil and 73% were proved developed reserves. Prior to the SP49 Acquisition, we owned a 43.5% working interest in certain of these assets, and Energy XXI owned a 56.5% working interest in certain of these assets as well as 100% interest in additional assets in the field. As a result of the SP49 Acquisition, we have become the sole working interest owner of the South Pass 49 field. We financed the SP49 Acquisition with borrowings of approximately $135 million under our credit facility and a $95 million capital contribution from EGC.  See Note 8, “Indebtedness” for more information regarding our credit facility.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments of $0.2 million to reflect an economic effective date of June 1, 2014.
	(In thousands)	1-Jun-14
	Oil and natural gas properties	$	231,271
	Asset retirement obligations		-1,086
	Net assets acquired	$	230,185
	The Nexen Acquisition
	On January 15, 2014, we acquired from Nexen Petroleum Offshore U.S.A., Inc. (“Nexen”) 100% working interest of certain shallow-water central GoM shelf oil and natural gas assets for $70.4 million, subject to customary adjustments to reflect the September 1, 2013, economic effective date (the “Nexen Acquisition”).  The assets we acquired comprise five leases in the Eugene Island 258/259 field (the “EI Interests”).  Estimated proved reserves as of the September 1, 2013 effective date consist of approximately 2.6 Mmboe of proved developed producing reserves, about 91% of which is oil. The Nexen Acquisition was financed with borrowings under our senior secured credit facility with BMO Capital Markets, as lead arranger, and Bank of Montreal, as administrative agent and a lender, and the other lender parties thereto (as amended and restated, the “Prior Senior Credit Facility”).
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments of $5.7 million to reflect an economic effective date of September 1, 2013.
	(In thousands)	1-Sep-13
	Oil and natural gas properties	$	82,897
	Asset retirement obligations		-18,165
	Net assets acquired	$	64,732
	The West Delta 29 Acquisition
	On September 26, 2013, we acquired from W&T Offshore, Inc. (“W&T”) an asset package consisting of certain GoM shelf oil and natural gas interests in the West Delta 29 field (the “WD29 Interests”) for $21.8 million in cash, subject to customary adjustments to reflect an economic effective date of January 1, 2013 (the “WD29 Acquisition”). We estimate that the proved reserves as of the January 1, 2013 economic effective date totaled approximately 0.7 Mmboe, of which 95% were oil and 58% were proved developed reserves. The WD29 Acquisition was funded with a portion of the proceeds from the sale of the BM Interests held by the qualified intermediary as described below.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $7.1 million to reflect an economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	16,544
	Asset retirement obligations		-1,398
	Net assets acquired	$	15,146
	Sale of Non-Operated Bay Marchand Asset
	On April 2, 2013, we sold certain shallow water GoM shelf oil and natural gas interests located within the non-operated Bay Marchand field (the “BM Interests”) to the property operator for $51.5 million in cash and the buyer’s assumption of liabilities recorded on our balance sheet of $11.3 million resulting in total consideration of $62.8 million, subject to customary adjustments to reflect the January 1, 2013 economic effective date. Our results for the year ended December 31, 2013 reflect a pre-tax gain of $28.1 million from this sale.
	The following table summarizes the carrying amount of the net assets sold and reflects final adjustments to the sale price provided for by the purchase and sale agreement of approximately $0.7 million to reflect the economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	35,298
	Asset retirement obligations		-3,959
	Other liabilities		-7,311
	Net assets sold	$	24,028
	The cash proceeds from this sale of assets were held on deposit with a qualified intermediary in contemplation of a potential tax-deferred exchange of properties and classified as restricted cash at June 30, 2013.  On September 26, 2013, we used $16.5 million of these proceeds to fund the WD29 Acquisition (defined and described above), which was a qualifying purchase for tax-deferral purposes. On September 29, 2013, the underlying escrow agreement expired, and the remaining amount of the deposit became unrestricted.
	The Hilcorp Acquisition
	On October 31, 2012, we acquired from Hilcorp Energy GOM Holdings, LLC (“Hilcorp”) 100% of the membership interests of Hilcorp Energy GOM, LLC (the “Hilcorp Acquisition”), which owned certain shallow water GoM shelf oil and natural gas interest (the “Hilcorp Properties”) for $550.0 million in cash, subject to customary adjustments to reflect an economic effective date of July 1, 2012.  As of December 31, 2012, the Hilcorp Properties had estimated proved reserves of approximately 37.2 Mmboe, of which 49% were oil and 58% were proved developed reserves.
	The Hilcorp Acquisition was financed with cash on hand, the net proceeds from the sale of $300 million in aggregate principal amount of 8.25% senior notes due 2018 (the “2012 Senior Notes”) and borrowings under our Prior Senior Credit Facility.  See Note 8, “Indebtedness,” for more information regarding our 2012 Senior Notes.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $5.7 million to reflect an economic effective date of July 1, 2012.
	(In thousands)	1-Jul-12
	Oil and natural gas properties	$	698,660
	Asset retirement obligations		-150,959
	Net assets acquired	$	547,701
	During the quarter ended December 31, 2013, we completed the allocation of the Hilcorp Acquisition purchase price resulting in an increase in the acquired asset retirement obligation of $22.1 million.  This change was due primarily to changes in the timing of expected cash flows for the related abandonment and decommissioning activities.
	The South Timbalier Acquisition
	On May 15, 2012, we acquired from W&T an asset package consisting of certain shallow-water GoM shelf oil and natural gas interests in our South Timbalier 41 field (the “ST41 Interests”) for $32.4 million in cash, subject to customary adjustments to reflect an economic effective date of April 1, 2012. We estimate that the proved reserves as of the April 1, 2012 economic effective date totaled approximately 1.0 Mmboe, of which 51% were oil and 84% were proved developed reserves. Prior to the ST41 Acquisition, we owned a 60% working interest in these properties, and W&T owned a 40% working interest. As a result of the ST41 Acquisition, we have become the sole working interest owner of the South Timbalier 41 field. We funded the ST41 Acquisition with cash on hand.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $0.4 million to reflect an economic effective date of April 1, 2012.
	(In thousands)	April 1, 2012
	Oil and natural gas properties	$	33,206
	Asset retirement obligations		-1,878
	Net assets acquired	$	31,328
	We have accounted for our acquisitions using the acquisition method of accounting for business combinations, and therefore we have estimated the fair value of the assets acquired and the liabilities assumed as of their respective acquisition dates. In the estimation of fair value, management uses various valuation methods including (i) comparable company analysis, which estimates the value of the acquired properties based on the implied valuations of other similar operations; (ii) comparable asset transaction analysis, which estimates the value of the acquired operations based upon publicly announced transactions of assets with similar characteristics; (iii) comparable merger transaction analysis, which, much like comparable asset transaction analysis, estimates the value of operations based upon publicly announced transactions with similar characteristics, except that merger analysis analyzes public to public merger transactions rather than solely asset transactions; and (iv) discounted cash flow analysis. The fair value is based on subjective estimates and assumptions, which are inherently subject to significant uncertainties which are beyond our control. These assumptions represent Level 3 inputs, as further discussed in Note 11, “Fair Value Measurements.”
	Results of Operations and Pro Forma Information
	Revenues and lease operating expenses attributable to acquired interests and properties were as follows:
			Period from			Period from January 1, 2014 through June 3,		Year Ended December 31,
			June 4, 2014 through June 30,
			2014			2014		2013		2012
			(In thousands)			(In thousands)
	SP49 Interests:
	Revenues		$	5,126		$	-	$	-	$	-
	Lease operating expenses		$	600		$	-	$	-	$	-
	EI Interests:
	Revenues		$	4,379		$	17,565	$	-	$	-
	Lease operating expenses		$	1,151		$	7,264	$	-	$	-
	WD29 Interests:
	Revenues		$	1,232		$	5,681	$	3,011	$	-
	Lease operating expenses		$	12		$	89	$	44	$	-
Hilcorp Properties:
Revenues		$	22,455		$	100,571	$	208,241	$	37,978
Lease operating expenses		$	7,489		$	29,189	$	74,404	$	10,982
ST41 Interests:
Revenues		$	843		$	3,406	$	11,189	$	9,262
Lease operating expenses		$	148		$	1,217	$	2,468	$	1,760
We have determined that the presentation of net income attributable to the acquired interests and properties is impracticable due to the integration of the related operations upon acquisition. We incurred fees of approximately $0.3 million related to the SP49 Acquisition which were included in general and administrative expenses in the accompanying consolidated statement of operations for the period June 4, 2014 through June 30, 2014.  We incurred fees of approximately $0.1 million related to the Nexen Acquisition which were included in general and administrative expenses in the accompanying consolidated statement of operations for the period January 1, 2014 through June 3, 2014.  We incurred fees of approximately $0.5 million related to the Hilcorp Acquisition and approximately $0.1 million related to the ST41 Acquisition, which were included in general and administrative expenses in the accompanying consolidated statement of operations for the year ended December 31, 2012.
The following supplemental pro forma information presents consolidated results of operations as if the WD 29 Acquisition, the Nexen Acquisition and SP 49 Acquisition had occurred on January 1, 2013. The supplemental unaudited pro forma information was derived from a) our historical consolidated statements of operations, b) the audited statement of revenues and direct operating expenses of the SP49 Interests for the year ended December 31, 2013, c) the unaudited statement of revenues and direct operating expenses of the SP49 Interests for the five month and three day period ended June 3, 2014, and d) unaudited revenues and direct operating expenses of the WD 29 Interests and the EI Interests as derived from the records of the applicable seller provided to us in connection with the acquisitions.  This information does not purport to be indicative of results of operations that would have occurred had the acquisitions occurred on January 1, 2013, nor is such information indicative of any expected future results of operations.
		PRO FORMA
		Period from		Year Ended
		1-Jan-14		December 31,
		through June 3,
		2014		2013
	(in thousands, except per share data)
Revenue		$	303,742	$	823,436
Net income (loss)			-15,546		122,391
Basic earnings (loss) per share			-0.4		3.13
Diluted earnings (loss) per share			-0.4		3.09

Common_Stock

Common Stock	1 Months Ended
	Jun. 30, 2014
Common Stock [Abstract]	'
Common Stock	'
	(4) Common Stock
	The Merger became effective on June 3, 2014. For each share of our common stock held, shareholders had the right to elect to receive $39.00 in cash or 1.669 shares of Energy XXI common stock or $25.35 in cash and 0.584 of a share of Energy XXI common stock.  As a result of the Merger our securities were suspended from trading on June 4, 2014.  Our common stock was then removed from listing and registration on the New York Stock Exchange (the “NYSE”) on July 15, 2014.
	We had reserved up to 3,574,000 shares of common stock for the issuance of restricted shares and option shares under our 2009 Long-Term Incentive Plan, with 1,087,347 shares remaining for issuance. See Note 13, “Employee Benefit Plans” for information regarding the 2009 Long-Term Incentive Plan.
	In August 2011, the former Board of Directors of EPL authorized a program for the repurchase of our outstanding common stock for up to an aggregate cash purchase price of $20.0 million and increased the program to $40.0 million in May 2012. In July 2013, the former Board of Directors increased the program to $80.0 million. Through December 31, 2013, we executed trades to repurchase 1,799,000 shares at an aggregate cash purchase price of approximately $29.7 million. Such shares were held in treasury and could be used to provide available shares for possible resale in future public or private offerings and our employee benefit plans. The repurchases were carried out in accordance with certain volume, timing and price constraints imposed by the SEC rules applicable to such transactions. In July 2013, our Prior Senior Credit Facility was amended to increase the limit applicable to certain restricted payments, which includes share repurchases, permitted by the agreement.
	Covenants in certain debt instruments to which we are a party, including the indenture related to our 8.25% Senior Notes, place certain restrictions and conditions on our ability to pay dividends on our common stock.

Earnings_per_Share

Earnings per Share	1 Months Ended
	Jun. 30, 2014
Earnings per Share [Abstract]	'
Earnings per Share	'
	(5) Earnings Per Share
	The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.
		Period from January 1, 2014		Year Ended December 31,
		through June 3,
		2014		2013		2012		2011
				(in thousands, except per share data)
	Income (numerator):
	Net income (loss)	$	-22,956	$	85,274	$	58,810	$	26,611
	Net income attributable to participating securities		-		-943		-455		-77
	Net income (loss) attributable to common shares	$	-22,956	$	84,331	$	58,355	$	26,534
	Weighted average shares (denominator):
	Weighted average shares—basic		38,730		38,730		38,885		39,946
	Dilutive effect of stock options		-		506		149		104
	Weighted average shares—diluted		38,730		39,236		39,034		40,050
	Basic earnings (loss) per share	$	-0.59	$	2.18	$	1.50	$	0.66
	Diluted earnings (loss) per share	$	-0.59	$	2.15	$	1.50	$	0.66
	The following table indicates the number of shares underlying outstanding stock-based awards excluded from the computation of dilutive weighted average shares because their effect was antidilutive for the periods indicated.
		Period from		Year Ended December 31,
		1-Jan-14
		through June 3,
		2014		2013		2012		2011
		(in thousands)		(in thousands)
	Weighted average shares		941		273		687		442

Property_and_Equipment

Property and Equipment	1 Months Ended
	Jun. 30, 2014
Property and Equipment [Abstract]	'
Property and Equipment	'
	(6) Property and Equipment
	The following table summarizes our property and equipment.
		June 30,
		2014
		(In thousands)
	Proved oil and natural gas properties	$	2,316,306
	Unevaluated oil and natural gas properties		908,483
	Other		3,173
	Less:  accumulated depreciation, depletion and amortization		-22,775
	Total property and equipment, net of accumulated depreciation, depletion and amortization	$	3,205,187
		December 31,
		2013		2012
		(In thousands)
	Proved oil and natural gas properties	$	2,307,891	$	1,982,657
	Unproved oil and natural gas properties		39,191		36,992
	Other		8,137		5,998
	Less:  accumulated depreciation, depletion and amortization		-618,788		-427,580
	Total property and equipment, net of accumulated depreciation, depletion	$	1,736,431	$	1,598,067
	and amortization
	At June 30, 2014 and December 31, 2013, we did not have any exploratory projects that were suspended for a period greater than one year.
	Substantially all of our oil and natural gas properties serve as collateral under our credit facility.
	We recognized impairments of $0.1 million, $2.9 million, $8.9 million and $32.5 million in the period from January 1, 2014 through June 3, 2014 and the years ended December 31, 2013, 2012 and 2011, respectively.
	Impairments for the year ended December 31, 2013 were primarily related to reservoir performance at a gas well in one of our smaller producing fields.  This field was determined to have future net cash flows less than its carrying value resulting in the write down of this property to its estimated fair value.
	Impairments for the year ended December 31, 2012 were primarily due to the decline in our estimate of future natural gas prices affecting certain of our natural gas producing fields and to reservoir performance at two of those fields. These fields were determined to have future net cash flows less than their carrying values resulting in the write down of these properties to their estimated fair values.  We also recorded impairments for undeveloped leases that are expiring in 2013 for which we had no development plans.
	Impairments for the year ended December 31, 2011 were primarily related to our natural gas producing fields and our deepwater producing well (primarily natural gas). Impairments related to our deepwater producing well were primarily due to the decline in our estimate of future natural gas prices, reservoir performance and higher estimated operating costs. Additional impairments for the year ended December 31, 2011 were primarily related to reservoir performance at other natural gas producing fields.

Asset_Retirement_Obligations

Asset Retirement Obligations	1 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	(7) Asset Retirement Obligations
	The following table reconciles the beginning and ending aggregate recorded amount of our asset retirement obligations (“ARO”).
		Period from		Period from January 1, 2014		Year Ended December 31,		Year Ended December 31,
		June 4, 2014 through June 30,		through June 3,
		2014		2014		2013		2012
		(in thousands)		(in thousands)
	Beginning of period total	$	260,161	$	255,450	$	235,110	$	99,347
	Accretion expense		2,022		11,771		28,299		15,565
	Liabilities assumed in acquisitions		1,086		18,165		23,541		132,109
	Pushdown accounting fair value adjustment		13,213		-		-		-
	Liabilities incurred		-		-		1,187		1,210
	Revisions		-		7,415		24,586		22,308
	Liabilities associated with assets sold		-		-		-3,965		-
	Liabilities settled		-3,787		-32,640		-53,308		-35,429
	End of period total		272,695		260,161		255,450		235,110
	Less: End of period, current portion		-39,831		-39,859		-51,601		-30,179
	End of period, noncurrent portion	$	232,864	$	220,302	$	203,849	$	204,931
	The fair value adjustment recorded in pushdown accounting resulted from conforming to Energy XXI’s inflation and discount rate assumptions.
	We revise our estimates of ARO as information about material changes to the liability becomes known.  During the year ended December 31, 2013, our revisions include an increase to our estimated ARO of $20.8 million related to our only remaining four non-producing wellbores in our non-operated deepwater properties.  These deepwater abandonment costs were primarily attributable to changes in regulatory interpretations and enforcement by the Bureau of Safety and Environmental Enforcement (“BSEE”) in the deepwater that increased the required scope of work. As a result, we recorded an associated $20.8 million loss on abandonment activities, which is included in Other costs and expenses in our consolidated statements of operations for the year ended December 31, 2013.

Indebtedness

Indebtedness	1 Months Ended
	Jun. 30, 2014
Indebtedness [Abstract]	'
Indebtedness	'
	(8) Indebtedness
	The following table sets forth our indebtedness.
			June 30,		December 31,		December 31,
			2014		2013		2012
			(In thousands)		(In thousands)
	8.25% senior notes due 2018		$	550,566	$	497,355	$	494,911
	Revolving credit sub-facility			475,000		-		-
	Senior credit facility			-		130,000		195,000
	Total indebtedness			1,025,566		627,355		689,911
	Current portion of indebtedness			-		-		-
	Noncurrent portion of indebtedness		$	1,025,566	$	627,355	$	689,911
	8.25% Senior Notes
	The 8.25% senior notes consist of $510.0 million in aggregate principal amount ($550.6 million carrying value) of our 8.25% senior notes due 2018 (the “8.25% Senior Notes”) issued under an Indenture dated February 14, 2011 (the “2011 Indenture”). The 8.25% Senior Notes bear interest from the date of their issuance at an annual rate of 8.25% with interest due semi-annually, in arrears, on February 15th and August 15th of each year. The 8.25% Senior Notes are fully and unconditionally guaranteed, jointly and severally, on an unsecured senior basis initially by each of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries). The 8.25% Senior Notes will mature on February 15, 2018.  At June 30, 2014, the effective interest rate on the 8.25% Senior Notes was approximately 5.8%, reflecting the fair value adjustment recorded in pushdown accounting.  Prior to pushdown accounting, the effective interest rate was approximately 9.1%.  We issued the 8.25% Senior Notes in two different private placements, described below.
	On February 14, 2011, we issued the $210.0 million in aggregate principal amount of our 8.25% senior notes due 2018 (the “2011 Senior Notes”) under the 2011 Indenture.  We used the net proceeds from the offering of the 2011 Senior Notes of $202.0 million, after deducting the initial purchasers’ discount and offering expenses payable by us, to acquire an asset package for a purchase price of $200.7 million, before adjustments to reflect an economic effective date of January 1, 2011.
	On October 25, 2012, we issued the $300.0 million in aggregate principal amount of our 2012 Senior Notes under an Indenture dated as of October 25, 2012 (the “2012 Indenture”).  We used the net proceeds from the offering of the 2012 Senior Notes of $289.5 million, after deducting the initial purchasers’ discount, to fund a portion of the Hilcorp Acquisition.  The purchase price of the 2012 Senior Notes included $4.8 million of accrued interest for the period from August 15, 2012 to October 25, 2012, which we recorded as interest payable.
	The 2012 Senior Notes were offered in a private placement only to qualified institutional buyers under Rule 144A promulgated under the Securities Act of 1933, as amended (the “Securities Act”), or to persons outside of the United States in compliance with Regulation S promulgated under the Securities Act. The 2012 Senior Notes had terms that were substantially identical to the terms of our 2011 Senior Notes. Pursuant to a registration rights agreement executed as part of the sale of the 2012 Senior Notes, we issued publicly registered additional notes under our 2011 Indenture in exchange for the 2012 Senior Notes. As a result of this exchange offer, 100% in aggregate principal amount of the 2012 Senior Notes was exchanged for the notes under the 2011 Indenture, effective as of June 10, 2013.  All of the 8.25% Senior Notes are now issued under the 2011 Indenture, regardless of which private placement they were issued under.
	On April 18, 2014, we entered into a supplemental indenture (the “Supplemental Indenture”) to the 2011 Indenture, by and among us, the guarantors party thereto, and U.S. Bank National Association, as trustee (the “8.25% Senior Notes Trustee”), governing our 8.25% Senior Notes. We entered into the Supplemental Indenture after the receipt of consents from the requisite holders of the 8.25% Senior  Notes in accordance with the terms and conditions of the Consent Solicitation Statement dated April 7, 2014, pursuant to which Energy XXI had solicited consents (the “Consent Solicitation”) from the holders of the 8.25% Senior Notes to make certain proposed amendments to certain definitions set forth in the Indenture (the “Proposed COC Amendments”), as reflected in the Supplemental Indenture. The Consent Solicitation was made as permitted by the Merger Agreement. On April 18, 2014, Energy XXI had received valid consents from holders of an aggregate principal amount of $484.1 million of the 8.25% Senior Notes and those consents had not been revoked prior to the Consent Time. As a result, the requisite holders of the 8.25% Senior Notes had consented to the Proposed COC Amendments, upon the terms and subject to the conditions set forth in the Consent Solicitation Statement. Accordingly, we, the guarantors party thereto and the Trustee entered into the Supplemental Indenture. Subject to the terms and conditions set forth in the Statement, Energy XXI paid an aggregate cash payment equal to $2.50 per $1,000 principal amount of 8.25% Senior Notes for which consents to the Proposed COC Amendments were validly delivered and unrevoked.
	On or after February 15, 2015, we may on any one or more occasions redeem all or a part of the 8.25% Senior Notes upon not less than 30 nor more than 60 days’ notice, at the redemption prices (expressed as percentages of principal amount) set forth below, plus accrued and unpaid interest and special interest, if any, on the notes redeemed, to the applicable date, if redeemed during the twelve-month period beginning on February 15 of the years indicated below, subject to the rights of holders of notes on the relevant record date to receive interest on the relevant interest payment date:
	Year	Percentage
	2015	104.125%
	2016	102.063%
	2017 and thereafter	100.000%
	Any such redemption and notice may, in our discretion, be subject to the satisfaction of one or more conditions, precedent, including, but not limited to, the occurrence of a change of control. Unless we default in the payment of the redemption price, interest will cease to accrue on the 8.25% Senior Notes or portions thereof called for redemption on the applicable redemption date.    In addition, we may, at our option, on any one or more occasions redeem all or a part of the 8.25% Senior Notes prior to February 15, 2015 at a redemption price equal to 100% of the principal amount of the 8.25% Senior Notes redeemed plus a “make-whole” premium as of, and accrued and unpaid interest to the redemption date.
	If we experience a change of control (as defined in the 2011 Indenture), each holder of the 8.25% Senior Notes will have the right to require us to repurchase all or any part (equal to $2,000 or an integral multiple of $1,000 in excess thereof) of the 8.25% Senior Notes at a price in cash equal to 101% of the aggregate principal amount of the 8.25% Senior Notes repurchased, plus accrued and unpaid interest to the date of repurchase. If we engage in certain asset sales, within 360 days of such sale, we generally must use the net cash proceeds from such sales to repay outstanding senior secured debt (other than intercompany debt or any debt owed to an affiliate), to acquire all or substantially all of the assets, properties or capital stock of one or more companies in our industry, to make capital expenditures or to invest in our business. When any such net proceeds that are not so applied or invested exceed $20.0 million, we must make an offer to purchase the 8.25% Senior Notes and other pari passu debt that is subject to similar asset sale provisions in an aggregate principal amount equal to the excess net cash proceeds. The purchase price of each 8.25% Senior Note (or other pari passu debt) so purchased will be 100% of its principal amount, plus accrued and unpaid interest to the repurchase date, and will be payable in cash.
	The 2011 Indenture, among other things, limits our ability to: (i) declare or pay dividends, redeem subordinated debt or make other restricted payments; (ii) incur or guarantee additional debt or issue preferred stock; (iii) create or incur liens; (iv) incur dividend or other payment restrictions affecting restricted subsidiaries; (v) consummate a merger, consolidation or sale of all or substantially all of our assets; (vi) enter into sale-leaseback transactions, (vii) enter into transactions with affiliates; (viii) transfer or sell assets; (ix) engage in business other than our current business and reasonably related extensions thereof; or (x) issue or sell capital stock of certain subsidiaries. These covenants are subject to a number of important exceptions and qualifications set forth in the 2011 Indenture.
	Prior Senior Credit Facility
	On February 14, 2011, we entered into our senior secured credit facility with BMO Capital Markets, as lead arranger, and Bank of Montreal, as administrative agent and a lender, and the other lender parties thereto (as amended and restated, the “Prior Senior Credit Facility”). The original terms of our Prior Senior Credit Facility established a revolving credit facility with a four-year term that could be used for revolving credit loans and letters of credit up to an aggregate principal amount of $250.0 million. On October 31, 2012, in connection with the Hilcorp Acquisition, through an amendment and restatement of our Prior Senior Credit Facility, the aggregate commitment under this facility was increased to a maximum of $750.0 million and the maturity date was extended to October 31, 2016.  The maximum amount of letters of credit that could be outstanding at any one time was $20.0 million. The amount available under the revolving credit facility was limited by the borrowing base. The borrowing base under our Prior Senior Credit Facility had been determined at the discretion of the lenders, based on the collateral value of our proved reserves and was subject to potential special and regular semi-annual redeterminations. On October 31, 2012, the borrowing base under the expanded credit facility was increased from $200.0 million to $425.0 million. On November 26, 2013, we completed our semi-annual redetermination and our borrowing base remained at $425.0 million. In January 2014, our lenders approved a $50.0 million increase in our borrowing base under the $750.0 million facility, increasing our borrowing base to $475.0 million. In addition, in July 2013, our Prior Senior Credit Facility was amended to increase the limit applicable to certain restricted payments permitted by the agreement to accommodate our expanded stock repurchase program. Prior to the Merger, we had increased our borrowings under our Prior Senior Credit Facility to $475.0 million in order to fund the purchase of the SP49 Interests and certain costs associated with the Merger. Immediately prior to the Merger, we had $475 million outstanding under our Prior Senior Credit Facility.  As of December 31, 2013, we had $130.0 million outstanding under our Prior Senior Credit Facility.  Our Prior Senior Credit Facility was refinanced in connection with the Merger.  See “Revolving Credit Sub-Facility” described below.
	The interest rate spread on loans and letters of credit under our Prior Senior Credit Facility was based on the level of utilization and ranged from a base rate plus a margin of 0.75% to 1.75% for base rate borrowings and LIBOR plus a margin of 1.75% to 2.75% for LIBOR borrowings.  Commitment fees ranging from 0.375% to 0.50% were payable on the unused portion of the borrowing base.
	Revolving Credit Sub-Facility
	On June 3, 2014, EGC, EPL, the lenders thereunder and the other parties thereto entered into, entered into the Eighth Amendment dated May 23, 2014 (“the Eighth Amendment”) to the second amended and restated first lien credit agreement (“First Lien Credit Agreement”). The Eighth Amendment generally set out the consent of the lenders thereunder to the consummation of the acquisition of EPL by EGC on such date and contained provisions facilitating such acquisition, including providing some of the financing for it. Most of the terms of the Eighth Amendment generally are in regards to incorporating the concept of EPL as a separate “borrower” for purposes of the First Lien Credit Agreement as described below.
	Pursuant to the Eighth Amendment, the borrowing base for EGC was established at $1.5 billion until the next redetermination of such borrowing base pursuant to the terms of the First Lien Credit Agreement. Of this borrowing base amount, EGC established a sub-facility pursuant to the Eighth Amendment for us with a borrowing base of $475 million.  The maturity date of the revolving credit facility is April 9, 2018, provided that the facility will mature immediately if the EGC 9.25% senior notes are not retired or refinanced by June 15, 2017 or the 8.25% Senior Notes are not retired or refinanced by August 15, 2017. Upon the effectiveness of the Eighth Amendment, we immediately borrowed the entire $475 million to refinance the outstanding indebtedness we had under the terms of our Prior Senior Credit Facility. As a result, on June 3, 2014, we repaid all amounts outstanding under the Prior Senior Credit Facility and our Prior Senior Credit Facility was terminated on June 3, 2014. As of June 30, 2014, we had $475.0 million outstanding under the Eighth Amendment.
	The borrowing base for this sub-facility is subject to redetermination from time to time generally on the same basis as is the overall borrowing base under the First Lien Credit Agreement. Under the Eighth Amendment, EGC and its subsidiaries, other than EPL, have guaranteed and secured the indebtedness of EPL and its subsidiaries, but EPL and its subsidiaries have not commensurately guaranteed the obligations of EGC and its other subsidiaries. However, per the terms of the First Lien Credit Agreement, immediately upon our retirement of our obligations in respect of our outstanding 8.25% Senior Notes due 2018, we are required to guarantee and secure the obligations generally of EGC and its subsidiaries and our sub-facility shall terminate and the entire borrowing base amount shall thereupon be available to EGC for credit extensions under the terms of the First Lien Credit Agreement.
	Interest accrues and is payable on the EPL sub-facility on the same basis as principal amounts outstanding generally under the First Lien Credit Agreement, which bears interest based on the borrowing base usage, at the applicable LIBOR, plus applicable margins ranging from 1.75% to 2.75% or an alternate base rate, based on the federal funds effective rate plus applicable margins ranging from 0.75% to 1.75%.
	On September 5, 2014, we and EGC received written confirmation from the administrative agent under the First Lien Credit Agreement that they had received signature pages from all of the lenders under the First Lien Credit Agreement for the Ninth Amendment to the Second Amended and Restated First Lien Credit Agreement, dated as of September 5, 2014 (the “Amendment”).  The Amendment also became effective as of such date based on satisfaction of the conditions to such effectiveness provided in the Amendment.  The Amendment provides for, among other things, an adjustment to the total leverage ratio covenant under the First Lien Credit Agreement as requested by EGC.  Under the Amendment, the total leverage of EGC and its consolidated subsidiaries may not exceed 4.25 times the amount of EBITDA of EGC and its consolidated subsidiaries for the fiscal quarters ended June 30, 2014, September 30, 2014, December 31, 2014 and March 31, 2015 and may not exceed 4.00 times the amount of EBITDA for each fiscal quarter ending June 30, 2015 and thereafter.  Prior to the Amendment, the total leverage ratio of EGC and its consolidated subsidiaries was required not to exceed 3.50 times EBITDA, although EGC and EPL had obtained a waiver to such requirement for the fiscal quarters ended June 30, 2014 and September 30, 2014 on August 22, 2014.  The Amendment also provides for a further covenant of EGC and its subsidiaries to limit the amount of their secured debt to an amount not to exceed 1.75 times the EBITDA of EGC and its consolidated subsidiaries for the fiscal quarters ended September 30, 2014, December 31, 2014 and March 31, 2015 and 1.50 times EBITDA for any fiscal quarter ending June 30, 2015 and thereafter.  Generally, the foregoing amendments under the First Lien Credit Agreement have arisen as EGC continues to consolidate our financial condition and results of operations within the scope of EGC and its subsidiaries.
	Pursuant to the terms of the Amendment, the lenders under the First Lien Credit Agreement also maintained the borrowing base for EGC at $1,500,000,000, of which such amount $475,000,000 is the borrowing base for EPL under the sub-facility established for EPL under the First Lien Credit Agreement.  These respective borrowing bases were set in accordance with the regular annual process for determination of the borrowing bases and the borrowing bases are to remain effective until the next redetermination thereof under the terms of the First Lien Credit Agreement.

Concentrations

Concentrations	1 Months Ended
	Jun. 30, 2014
Concentrations [Abstract]	'
Concentrations	'
	(9) Concentrations
	Significant Customers
	We had oil and natural gas sales to three customers accounting for 55%,  23% and 11%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the period from June 4, 2014 through June 30, 2014.    We had oil and natural gas sales to three customers accounting for 52%,  23% and 10%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the period from January 1, 2014 through June 3, 2014. We had oil and natural gas sales to three customers accounting for 63%, 24% and 6%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the year ended December 31, 2013.  We had oil and natural gas sales to three customers accounting for 45%, 31% and 11%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the year ended December 31, 2012.
	Geographic Concentration
	Virtually all of our current operations and proved reserves are concentrated in the Gulf of Mexico region.  Therefore, we are exposed to operational, regulatory and other risks associated with the Gulf of Mexico, including the risk of adverse weather conditions.  We maintain insurance coverage against some, but not all, of the operating risks to which our business is exposed.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities

1 Months Ended

Jun. 30, 2014

Derivative Instruments and Hedging Activities [Abstract]

'

Derivative Instruments and Hedging Activities

'

(10) Derivative Instruments and Hedging Activities

We enter into derivative instruments to reduce exposure to fluctuations in the price of oil and natural gas for a portion of our production. Our fixed-price swaps fix the sales price for a limited amount of our production and, for the contracted volumes, eliminate our ability to benefit from increases in the sales price of the production. Derivative instruments are carried at their fair value on the consolidated balance sheets as Fair value of commodity derivative instruments.  Prior to the Merger, we did not designate derivative instruments as hedges.  All gains and losses due to changes in fair market value and contract settlements were recorded in Gain (loss) on derivative instruments in Other income (expense) in the consolidated statements of operations.

Subsequent to the Merger, we designate our derivative financial instruments as cash flow hedges. No components of the cash flow hedging instruments are excluded from the assessment of hedge ineffectiveness. Any gains or losses resulting from the change in fair value from hedging transactions that are determined to be ineffective are recorded as a loss (gain) on derivative financial instruments, whereas gains and losses from the settlement of cash flow hedging contracts are recorded in crude oil and natural gas revenue in the same period during which the hedged transactions are settled.    See Note 11 for information regarding fair values of our derivative instruments.

Energy XXI assumed our existing hedges and expects to carry those hedges through the end of contract term beginning from June 2014 through December 2015.  Our oil contracts are primarily swaps and benchmarked to Argus-LLS and Brent.

The energy markets have historically been very volatile, and there can be no assurances that crude oil and natural gas prices will not be subject to wide fluctuations in the future. While the use of hedging arrangements helps to limit the downside risk of adverse price movements, they may also limit future gains from favorable price movements.

The following tables set forth our derivative instruments outstanding as of June 30, 2014 for periods prior to the Merger.  Prior to the Merger, we did not elect to designate derivative instruments as hedges.

Oil Contracts

Fixed-Price Swaps

Daily Average

Average

Volume

Volume

Swap Price

Remaining Contract Term

(Bbls)

(Bbls)

($/Bbl)

July 2014 - December 2014

8,769

1,613,550

92.84

January 2015 - December 2015

1,500

547,500

97.70

Gas Contracts

Type

Average

Weighted Average Contract Price

($/Mmbtu)

of

Volume

Swap Price

Sub

Remaining Contract Term

Contract

(Mmbtu)

($/Mmbtu)

Floor

Floor

Ceiling

July 2014 - December 2014

Three-Way Collars

1,257,000

3.25

4.00

4.76

July 2014 - December 2014

Put Spreads

583,000

3.25

4.00

July 2014 - December 2014

Fixed Price Swaps

920,000

4.01

January 2015 - December 2015

Fixed Price Swaps

1,569,500

4.31

For the period from June 4, 2014 through June 30, 2014, we reclassified from AOCI a loss of approximately $1.6 million to oil and natural gas revenue.  The amount expected to be reclassified from other comprehensive income to income in the next 12 months is a gain of $8.8 million ($5.7 million net of tax) on our commodity hedges.  The estimated and actual amounts are likely to vary significantly due to changes in market conditions.

The following table presents information about the components of loss on derivative instruments for periods prior to the Merger, during which we did not elect to designate derivative instruments as hedges.

Period from

Years Ended December 31,

1-Jan-14

through

June 3,

2014

2013

2012

2011

(in thousands)

Change in fair market value

$

6,996

$

-20,884

$

-9,491

$

11,475

Loss on settlement

-26,416

-11,477

-3,814

-17,345

Total loss on derivative instruments

$

-19,420

$

-32,361

$

-13,305

$

-5,870

We monitor the creditworthiness of our counterparties.  However, we are not able to predict sudden changes in counterparties’ creditworthiness.  In addition, even if such changes are not sudden, we may be limited in our ability to mitigate an increase in counterparty credit risk.  Possible actions would be to transfer our position to another counterparty or request a voluntary termination of the derivative contracts resulting in a cash settlement.  Should one of these financial counterparties not perform, we may not realize the benefit of some of our derivative instruments under lower commodity prices, and could incur a loss.  At June 30, 2014, we had no deposits for collateral with our counterparties.

Fair_Value_Measurements

Fair Value Measurements	1 Months Ended
	Jun. 30, 2014
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	(11) Fair Value Measurements
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. 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, 2014 and December 31, 2013, 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. We estimate the fair values of these instruments based on published forward commodity price curves, market volatility and contract terms as of the date of the estimate. The discount rate used in the discounted cash flow projections is based on published LIBOR rates. The fair values of commodity derivative instruments in an asset position include a measure of counterparty nonperformance risk, and the fair values of commodity derivative instruments in a liability position include a measure of our own nonperformance risk, each based on the current published issuer-weighted corporate default rates. 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 sets forth our financial assets and liabilities that are accounted for at fair value on a recurring basis.
		June 30,		December 31,
		2014		2013		2012
		(in thousands)
	Assets:
	Current	$	-	$	501	$	3,302
	Noncurrent		-		238		211
	Total gross fair value		-		739		3,513
	Less: counterparty set-off		-		-739		-3,513
	Total net fair value	$	-	$	-	$	-
	Liabilities:
	Current	$	26,440	$	29,636	$	10,026
	Noncurrent		2,140		2,136		3,637
	Total gross fair value		28,580		31,772		13,663
	Less: counterparty set-off		-		-739		-3,513
	Total net fair value	$	28,580	$	31,033	$	10,150
	The carrying values reported in the consolidated balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximate fair value due to the short term maturities of these instruments. The fair value for the 8.25% Senior Notes is based on quoted prices, which are Level 1 inputs within the fair value hierarchy. The carrying value of the Senior Credit Facility approximates its fair value because the interest rates are variable and reflective of market rates, which are Level 2 inputs within the fair value hierarchy.
	The following table sets forth the carrying values and estimated fair values of our long-term indebtedness.
		30-Jun-14				31-Dec-13				31-Dec-12
		(In thousands)
			Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
	8.25% Senior Notes	$	550,566	$	545,700	$	497,355	$	546,338	$	494,911	$	524,600
	Revolving credit sub-facility		475,000		475,000		-		-		-		-
	Prior Senior Credit Facility		-		-		130,000		130,000		195,000		195,000
	Total	$	1,025,566	$	1,020,700	$	627,355	$	676,338	$	689,911	$	719,600
	Under the successful efforts method of accounting, our assessment of possible impairment of proved oil and natural gas properties was based on our best estimate of future prices, costs and expected net future cash flows by property (generally analogous to a field or lease). An impairment loss was indicated if undiscounted net future cash flows were less than the carrying value of a property. The impairment expense was measured as the shortfall between the net book value of the property and its estimated fair value, which was 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 were based on our estimates of future events, including projections of future oil and natural gas sales prices, amounts of recoverable oil and natural gas reserves, timing of future production,  future costs to develop and produce our oil and natural gas and discount factors. These inputs were Level 3 inputs within the fair value hierarchy. Impairments for the year ended December 31, 2013 were primarily related to reservoir performance at a gas well in one of our smaller producing fields. This field was determined to have future net cash flows less than its carrying value resulting in the write down of this property to its estimated fair value. Impairments for the year ended December 31, 2012 were primarily due to the decline in our estimate of future natural gas prices, which affected three of our natural gas producing fields and reservoir performance at two of those fields. These fields were determined to have future net cash flows less than their carrying values resulting in the write downs of these properties to their estimated fair values. We also recorded impairments for undeveloped leases that were expiring in 2013 for which we had no development plans.
	As addressed in Note 2, “Pushdown Accounting,” and Note 3, “Acquisitions,” we apply fair value concepts in estimating and allocating the fair value of assets acquired and liabilities assumed by Energy XXI in the Merger and assumed in acquisitions in accordance with acquisition accounting for business combinations. The inputs to the estimated fair values of assets acquired and liabilities assumed are described in Notes 2 and 3.

Income_Taxes

Income Taxes	1 Months Ended
	Jun. 30, 2014
Income Taxes [Abstract]	'
Income Taxes	'
	(12) Income Taxes
	We are a (U.S.) Delaware company and, as a result of the Merger, a direct subsidiary of EGC.  We are a member of a consolidated group of corporations for U.S. federal income tax purposes where Energy XXI, Inc., (the “U.S. Parent”) is the parent entity.  Energy XXI (Bermuda) Limited (the “Foreign Parent”) indirectly owns 100% of U.S. Parent, but is not a member of the U.S. consolidated group.  We operate through our various subsidiaries in the United States as they apply to our current ownership structure.  ASC Topic 740 provides that the income tax amounts presented in the separate financial statements of a subsidiary entity that is a member of a consolidated group should be based upon a reasonable allocation of the income tax amounts of that group.  We allocate income tax expense/benefit and deferred tax items between affiliates as if each affiliate prepared a separate U.S. income tax return for the reporting period.    We have recorded no income tax-related intercompany balances with affiliates.
	The components of our income tax provision (reflecting pushdown accounting as described in Notes 1 and 2) are as follows (in thousands):
		Period from June 4, 2014 through				Period from			Year Ended December 31,
		June 30,				1-Jan-14
						through
						June 3,
		2014				2014			2013			2012			2011
		(In thousands)				(In thousands)
	Current:
	Federal	$	-			$	-		$	-		$	-		$	-
	State		-				-			-			-			-
	Total current	$	-			$	-		$	-		$	-		$	-
	Deferred:
	Federal	$	-3,574			$	-4,318		$	-47,723		$	-28,719		$	-14,468
	State		-				-177			-1,964			-1,181			-354
	Total deferred	$	-3,574			$	-4,495		$	-49,687		$	-29,900		$	-14,822
	Total:
	Federal	$	-3,574			$	-4,318		$	-47,723		$	-28,719		$	-14,468
	State		-				-177			-1,964			-1,181			-354
	Total provision for income taxes.	$	-3,574			$	-4,495		$	-49,687		$	-29,900		$	-14,822
	The following is a reconciliation of the statutory federal income tax rate to our effective income tax rate:
		Percentage of Pretax Earnings
		Period from June 4, 2014 through				Period from			Year Ended December 31,
		June 30,				1-Jan-14
						through
						June 3,
		2014				2014			2013			2012			2011
	Statutory federal income tax rate		35.0	%			35.0	%		35.0	%		35.0	%		35.0	%
	State taxes		-				1.4			1.4			1.4			2.3
	Non-deductible items		-				-59.5			-			-			-
	Change in state tax rate		-				-			-			-2.7			-1.7
	Statutory depletion		-				-			-0.3			-0.4			-1
	Other		-				-1.2			0.7			0.4			1.2
	Effective income tax rate		35.0	%			-24.3	%		36.8	%		33.7	%		35.8	%
	Deferred income taxes primarily represent the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes.  The components of our deferred taxes are detailed in the table below (in thousands):
		June 30,			December 31,
		2014			2013			2012
		(In thousands)			(In thousands)
	Deferred tax assets:
	Federal and state net operating loss carryforwards	$	61,546		$	62,015		$	62,130
	Fair value of commodity derivative instruments		12,136			11,578			3,912
	Restricted stock awards and options		-			3,843			2,313
	Percentage depletion carryforward		-			5,003			4,575
	Basis differences in indebtedness		19,651			-			-
	Accruals and other		701			1,130			2,613
	Deferred tax asset		94,034			83,569			75,543
	Deferred tax liabilities:
	Property, plant and equipment, principally due to	$	550,435		$	193,191		$	136,016
	differences in depreciation
	Fair value of commodity derivative instruments		-			182			214
	Prepaid assets		1,663			1,482			1,778
	Accruals and other		1,147			2,577			1,907
	Deferred tax liabilities		553,245			197,432			139,915
	Net deferred tax liability		459,211			113,863			64,372
	Reflected in accompanying balance sheets as:
	Current deferred asset		24,587			8,949			3,322
	Non-current deferred liability		483,798			122,812			67,694
	Total net deferred tax liability	$	459,211		$	113,863		$	64,372
	As a result of our reorganization under Chapter 11 in 2009, the income from the discharge of indebtedness, represented for tax purposes as the excess of the principal and accrued interest on the debt discharged over the fair value of the stock of the reorganized company received in exchange for the discharged obligations, as defined by Internal Revenue Code (the “IRC”) Section 108 (“IRC 108”), reduced our net operating loss carryforwards (“NOLs”) by $97 million (“Tax Attribute Reduction”). Our remaining NOLs as of June 30, 2014 were approximately $191 million.
	At June 30, 2014, we had approximately $191 million of federal NOLs, of which approximately $28.8 million relates to excess tax benefits with respect to share-based compensation that have not been recognized in our consolidated financial statements. Our federal NOLs are available to reduce future federal taxable income subject to the limitations and estimates described below and the application of the tax rules and regulations. The NOLs begin expiring in the years 2025 through 2034.
	Ownership changes, as defined in IRC Section 382, limit the amount of NOLs that can be utilized annually to offset future taxable income and reduce our tax liability (“Section 382 Limitation”). In 2009, as part of our Chapter 11 reorganization, we had an ownership change which resulted in a Section 382 Limitation on the amount of NOLs available annually for use. Unused NOLs (those NOLs in existence immediately after the application of IRC 108) totaled $137 million. The annual limitation is approximately $21 million per year beginning in 2010 and, if unused, can be carried over and aggregated with limited NOLs in future years subject to the ultimate expiration of the NOLs. We have not used any limited NOLs since the reorganization. The amount of limited NOLs available for our 2014 short period federal tax return (for the period ending with the Merger) is approximately $130 million. We believe that we will be able to utilize all of our federal NOLs prior to their expiration.
	As of June 30, 2014, our 2010-2014 income tax years remain open to examination by the Internal Revenue Service. However, the statute of limitations for examination of NOLs and other similar attribute carryforwards does not begin to run until the year the attribute is utilized.  In some instances, state statutes of limitations are longer than those under U.S. federal tax law. As of the date of these financial statements, our 2013 state income tax returns have not been filed, although management expects to file such returns in a timely manner during 2014. We have no material uncertain tax positions as of June 30, 2014.  As of June 30, 2014, there is a cash credit carryforward of $36 thousand.

Employee_Benefit_Plans

Employee Benefit Plans	1 Months Ended
	Jun. 30, 2014
Employee Benefit Plans [Abstract]	'
Employee Benefit Plans	'
	(13) Employee Benefit Plans
	Employee Retention Plans
	We have two plans which provide that in the event of termination of employment in connection with a change of control of our company, our officers and employees are entitled to receive a multiple of their salaries and bonuses (typically 1.0 to 2.99 times such amount) and certain other benefits in a lump sum cash payment (the “EPL COC Plan”).  Additionally, all equity awards granted to participants would become fully vested, all stock options would become fully exercisable, and all restrictions on restricted shares and restricted share units would lapse. Upon a change of control, a participant would receive these acceleration benefits regardless of whether the participant’s employment was terminated.
	The Merger resulted in a change of control pursuant to the EPL COC Plan.  During the period January 1, 2014 through June 3, 2014, we recorded approximately $11.9 million for the cost of salaries, bonuses and certain other benefits under the EPL COC Plan.  Additionally, in March 2014 the former Compensation Committee established two cash bonus pools under the annual incentive plan to cover the period from January 1, 2014 until the effective date of the Merger.  In order to receive such bonus, a participant was required to perform services for the Company through the merger effective date.  During the period January 1, 2014 through June 3, 2014, we recorded approximately $5.5 million for the cost of these bonuses.
	Share-Based Compensation Plans
	In September 2009 the former Board of Directors adopted the 2009 Long Term Incentive Plan (the “2009 LTIP”). The purpose of the 2009 LTIP was to provide a means to enhance our profitable growth by attracting and retaining directors, officers and other key employees through affording such individuals a means to acquire and maintain stock ownership or awards the value of which is tied to the performance of our common stock. All directors, officers and other key employees providing services to the Company were potentially eligible to participate in the 2009 LTIP. The 2009 LTIP provided for grants of (i) incentive stock options qualified as such under income tax rules and regulations, (ii) stock options that do not qualify as incentive stock options, (iii) restricted stock awards, (iv) restricted stock units, (v) stock appreciation rights, (vi) bonus stock and awards in lieu of Company obligations, (vii) dividend equivalents in connection with other awards, (viii) deferred shares, (ix) performance units or shares, or (x) any combination of such awards (collectively referred to as “Awards”). The 2009 LTIP was administered by the former Compensation Committee of our Board of Directors prior to the Merger.
	Without stockholder or participant approval, the Board of Directors may amend, alter, suspend, discontinue or terminate the 2009 LTIP or the Compensation Committee’s authority to grant awards under the 2009 LTIP, except that any amendment or alteration of the 2009 LTIP, including any increase in any share limitation, shall be subject to the approval of the stockholders not later than the next annual meeting if stockholder approval is required by any state or federal law or regulation or the rules of any stock exchange or automated quotation system on which the common stock may then be listed or quoted.
	On the date of the 2013 Annual Meeting of Stockholders, the stockholders approved an increase in the maximum aggregate number of shares of our common stock that may be issued pursuant to any and all Awards under the 2009 LTIP from 2,474,000 shares to 3,574,000 shares, subject to adjustment due to recapitalization or reorganization, or related to forfeitures or the expiration of Awards, as provided under the 2009 LTIP. As of June 30, 2014, 1,087,347 shares remained available for future grants.
	The 2009 LTIP provides for the grant of stock options for which the exercise price, set at the time of the grant, will not be less than the fair market value per share at the date of grant. Stock options granted under the 2009 LTIP generally had a term of 10 years and vested ratably on an annual basis over a three-year period from the date of grant, other than the stock option grant to our former chief executive officer described in the following paragraph.
	Pursuant to an employment agreement and the 2009 LTIP, on September 30, 2009, our former chief executive officer was granted an option to purchase 68,116 shares of our common stock, which was memorialized in an option award agreement dated as of October 1, 2009 (the “Option Agreement”). The terms of the Option Agreement provided for an exercise price equal to $10.00 per share. The closing price of our common stock on the NYSE on September 30, 2009 was $7.46 per share. The option vested ratably on a monthly basis over a 36-month period from the date of grant; however, the vesting for the first six months of the vesting period (the “Initial Period”) was deferred until the end of the Initial Period and any remaining unvested portion vested ratably on a monthly basis over the remainder of the 36-month vesting period, subject to the executive remaining continuously employed. Under the original terms of the award agreement, vested stock options under the Option Agreement were to expire 30 months following the applicable vesting date of such stock options. On May 1, 2012, the former Compensation Committee modified the terms of the Option Agreement to extend the expiration of the stock options granted thereunder to September 30, 2019, resulting in additional compensation expense of $0.1 million in the year ended December 31, 2012.  Upon a change in control as defined in the 2009 LTIP, all stock options under the Option Agreement remain exercisable for a period of not less than 30 months following the change in control.
	Prior to February 2014, the former Compensation Committee approved a compensation program for each of our former non-employee directors which provided for the annual grant of a stock award with a market value of $100,000 (as measured on the date of the grant and prorated from the date of the grant, if applicable).  In February 2014, the former Compensation Committee approved an increase in the annual grant of a stock award from a market value of $100,000 to a market value of $125,000 (as measured on the date of the grant and prorated from the date of the grant, if applicable) for each of our former non-employee directors. Pursuant to the terms of the program, one-half of each stock award vested immediately on the date of grant, and the remaining one-half vested immediately prior to the next annual meeting of stockholders held after the grant date.  The grant date for these awards was typically on the date of our annual meeting of stockholders. Pursuant to this program and the 2009 LTIP, the four members of the former Board of Directors were awarded, in the aggregate, a total of 12,984 shares during the period from January 1, 2014 through June 3, 2014 and a total of 15,305 shares and 31,095 shares during the years ended December 31, 2013 and 2012, respectively. Pursuant to elections made by two directors applicable to certain of these awards, the receipt of such awards totaling 39,009 shares was deferred until such directors ceased to serve on our Board of Directors.
	In conjunction with the Merger, each option to purchase shares of Common Stock outstanding  immediately prior to the effective date of the Merger under the 2009 LTIP, whether or not then exercisable or vested, was deemed exercised pursuant to a cashless exercise for that number of shares of Common Stock (the “net exercise shares”) equal to (i) the number of shares of Common Stock subject to such stock option immediately prior to the effective date minus (ii) the number of whole and partial shares of Common Stock subject to such stock option that, when multiplied by $39.00 per share, was equal to the aggregate exercise price of such stock option. Each net exercise share deemed to be an outstanding share of Common Stock received merger consideration of $39.00 in cash and was not subject to proration like other holders of Common Stock that elected to receive all cash in the Merger.
	The following table sets forth our stock option activity for the period from January 1, 2014 through June 3, 2014.
		Options			Weighted-			Weighted-			Aggregate Intrinsic Value
					Average			Average
					Exercise			Remaining
					Price Per			Contractual
					Share			Terms
								(in years)			(in thousands)
	Outstanding on December 31, 2013		1,453,173		$	17.76
	Granted		143,114			26.79
	Exercised		-1,596,287			18.57
	Outstanding on June 3, 2014		-		$	-			-		$	-
	Exercisable on June 3, 2014		-		$	-			-		$	-
	The fair value of each stock option award was estimated on the date of grant using the Black-Scholes option valuation model using the weighted average assumptions in the table below.
		Period from				Year Ended December 31,
		1-Jan-14
		through June 3,
		2014				2013			2012			2011
	Black-Scholes option pricing model assumptions:
	Risk free interest rate		2.0	%		1.4	%		1.0	%		1.9	%
	Expected life (years)		6.0			6.0			6.0			6.0
	Expected volatility		57	%		56	%		56	%		53	%
	Dividend yield		-			-			-			-
	Expected volatility is generally based on the historical volatility of our stock over the period of time equivalent to the expected term of the options granted. As a result of our Chapter 11 reorganization in 2009 for purposes of determining expected volatility in 2014, 2013, and 2012, we included consideration of the historical volatility of the share prices of our peers over the relevant time periods in addition to our historical volatility before, during and after our reorganization. We disregarded our share price for the periods during which our stock price was impacted by factors leading up to the Chapter 11 filing and during the period of the Chapter 11 reorganization proceedings because we did not expect these events to reoccur during the expected term of the options. The expected term of options granted is generally derived from historical exercise patterns over a period of time, with consideration of the expected term of unvested options. However, because we did not have sufficient historical stock option exercise experience upon which to base an estimate of expected term, we used the simplified method for estimating expected term in 2014, 2013, and 2012. The risk-free interest rate was based on the interest rate on constant maturity bonds published by the Federal Reserve with a maturity commensurate with the expected term of the options granted.
	The weighted-average grant-date fair value of stock options granted during the period from January 1, 2014 through June 3, 2014, and the years ended December 31, 2013, 2012 and 2011 was $14.57, $14.50,  $8.84 and $7.97, respectively. The aggregate intrinsic value (the amount by which the market price of the stock on the date of exercise exceeded the market price of the stock on the date of grant) of stock options deemed exercised or exercised during the period from January 1, 2014 through June 3, 2014, and the years ended December 31, 2013, 2012 and 2011 was $32.6 million, $2.1 million, $0.5 million, and $0.1 million respectively.
	As provided by the EPL COC Plan, in conjunction with the Merger, each outstanding restricted stock award granted by the Company under the 2009 LTIP became fully vested and each holder had the right to make an election to receive the same types of merger consideration that each other holder of Common Stock had the right to receive.  The number of shares of the Company’s common stock that were issued as a result of the accelerated vesting of prior restricted stock grants totaled 471,080 shares.
	The following table sets forth the activity related to our non-vested share awards for the period from January 1, 2014 through June 3, 2014.
		Shares			Weighted-
					Average
					Grant-Date
					Fair Value
	Non-vested share awards outstanding at December 31, 2013		444,495		$	21.98
	Granted		161,370			25.08
	Vested		-605,865			22.81
	Non-vested share awards outstanding at June 3, 2014		-
	With the accelerated vesting of all non-vested share awards and the exercise of all outstanding stock options under the EPL COC Plan, all previously unrecognized share-based compensation expense related to these awards was recognized as of June 3, 2014.  The following table sets forth share-based compensation expense and related recognized tax benefits.
		Period from			Year Ended December 31,
		January 1, 2014 through June 3,
		2014			2013			2012			2011
	Compensation Expense:
	Stock Options	$	8,248		$	3,426		$	2,621		$	1,497
	Non-vested share awards		11,456			3,918			2,096			1,012
	Deferred Income Tax Benefit		-			2,704			1,726			936
	The Energy XXI Services, LLC 2006 Long-Term Incentive Plan
	Energy XXI maintains an incentive and retention program for their employees. Participation shares (or “Restricted Stock Units”) are issued from time to time at a value equal to Energy XXI’s common share price at the time of issue. The Restricted Stock Units generally vest equally over a three-year period. When vesting occurs, employees are paid an amount equal to the then current common share price times the number of Restricted Stock Units.  In conjunction with the Merger, a total of 349,481 Restricted Stock Units were granted to our employees.  We recognized compensation expense related to Restricted Stock Units of $0.4 million in the period from June 4, 2014 through June 30, 2014.
	401(k) Plan
	We also have a 401(k) Plan that covers all employees. We match 100% of each individual participant’s contribution not to exceed 6% of the participant’s compensation. Our matching contributions are made in cash. For the period from January 1, 2014 through June 30, 2014 and the years ended December 31, 2013, 2012 and 2011, we made matching contributions to the 401(k) Plan of approximately $0.3 million, $0.9 million, $0.8 million and $0.7 million, respectively.

Commitments_and_Contingencies

Commitments and Contingencies	1 Months Ended
	Jun. 30, 2014
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	(14) Commitments and Contingencies
	Lease Commitments.  We have operating leases for office space and equipment, which expire on various dates through September 2019. Expense relating to operating obligations for the period from June 4, 2014 through June 30, 2014, the period from January 1, 2014 through June 3, 2014, and the years ended December 31, 2013, 2012 and 2011 was $1.7 million, $3.0 million, $7.5 million, $2.4 million and $1.8 million, respectively. Future minimum commitments as of June 30, 2014 under these operating obligations are as follows (in thousands):
	2015		$	1,199
	2016			1,231
	2017			1,010
	2018			542
	2019			542
	Thereafter			135
	Future minimum commitments		$	4,659
	Seismic Commitments.  In connection with our exploration and development efforts, we are contractually committed to the acquisition of seismic data in the aggregate amount of $38 million to be incurred over the next three years.
	Drilling Rig Commitments.   The drilling rig commitments represent minimum future expenditures for drilling rig services. The expenditures for drilling rig services will exceed such minimum amounts to the extent we utilize the drilling rigs subject to a particular contractual commitment for a period greater than the period set forth in the governing contract. As of June 30, 2014, we have entered into five drilling rig commitments:
		1)		January 1, 2014 to July 15, 2014 at $107,500 per day.
		2)		February 15, 2014 to August 15, 2014 at $111,380 per day.
		3)		April 11, 2014 to September 15, 2014 at $112,000 per day.
		4)		July 1, 2014 to September 1, 2014 at $107,500 per day.
		5)		September 1, 2014 to October 1, 2014 at $107,500 per day.
	Litigation.    We are a defendant in a number of lawsuits and are involved in governmental and regulatory proceedings, all of which arose in the ordinary course of business, including, but not limited to, personal injury claims, royalty claims, contract claims, and environmental claims, including claims involving assets owned by acquired companies. While the ultimate outcome and impact on us cannot be predicted with certainty, management believes that the resolution of pending proceedings will not have a material adverse effect on our consolidated financial position, results of operations, or cash flows.
	In March and April, 2014, three alleged stockholders (the “Plaintiffs”) filed three separate class action lawsuits in the Court of Chancery of the State of Delaware on behalf of our stockholders against our Company,  our directors, Energy XXI, EGC, and Clyde Merger Sub, Inc., a Delaware corporation and wholly owned subsidiary of EGC (“Merger Sub” and collectively, the “defendants”). The Court of Chancery of the State of Delaware consolidated these lawsuits on May 5, 2014.  The consolidated lawsuit is styled In re EPL Oil & Gas Inc. Shareholders Litigation, C.A. No. 9460-VCN, in the Court of Chancery of the State of Delaware (the “lawsuit”).
	Plaintiffs allege a variety of causes of action challenging the Agreement and Plan of Merger between Energy XXI, EGC, Merger Sub, and EPL (the “Merger Agreement”),  including that (a) our directors have allegedly breached fiduciary duties in connection with the Merger and (b) we along with Energy XXI, EGC,  and Merger Sub, allegedly aided and abetted in these alleged breaches of fiduciary duties. Plaintiffs’ causes of action are based on their allegations that (i) the Merger allegedly provided inadequate consideration to our stockholders for their shares of our common stock; (ii) the Merger Agreement contained contractual terms — including, among others, the (A) “no solicitation,” (B) “competing proposal,” and (C) “termination fee” provisions — that allegedly dissuaded other potential acquirers from making competing offers for shares of our common stock; (iii) certain of our officers and directors allegedly received benefits — including (A) an offer for one of our directors to join the Energy XXI board of directors and (B) the triggering of change-in-control provisions in notes held by our executive officers — that were not equally shared by our stockholders; (iv) Energy XXI required our officers and directors to agree to vote their shares of our common stock in favor of the Merger; and (v) we provided, and Energy XXI obtained, non-public information that allegedly allowed Energy XXI to acquire us for inadequate consideration. Plaintiffs also allege that the Registration Statement filed on Form S-4 by us and Energy XXI on April 1, 2014 omits information concerning, among other things, (i) the events leading up to the Merger, (ii) our efforts to attract offers from other potential acquirors, (iii) our evaluation of the Merger; (iv) negotiations between us and Energy XXI, and (v) the analysis of our financial advisor. Based on these allegations, plaintiffs seek to have the Merger agreement rescinded. Plaintiffs also seek damages and attorneys’ fees.
	Defendants date to answer, move to dismiss, or otherwise respond to the lawsuit has been indefinitely extended. We cannot predict the outcome of the lawsuit or any others that might be filed subsequent to the date of the filing of this Transition Report; nor can we predict the amount of time and expense that will be required to resolve the lawsuit. The defendants intend to vigorously defend the lawsuit.
	Other.  We maintain restricted escrow funds in a trust for future abandonment costs at our East Bay property. The trust was originally funded with $15.0 million and, with accumulated interest, increased to $16.7 million at December 31, 2008. We may draw from the trust upon completion of qualifying abandonment activities at our East Bay field. At June 30, 2014, we had $6.0 million remaining in restricted escrow funds for decommissioning work in our East Bay field, which will remain restricted until substantially all required decommissioning in the East Bay field is complete. Amounts on deposit in the trust account are reflected in Restricted cash on our 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. The oil purchaser’s initial estimate of the oil volumes misallocated to us was approximately 74,000 barrels, which may have been valued at up to $6.9 million based on information provided by the oil purchaser. We had previously recorded an amount that we believed may have been payable related to a potential reallocation, which amount was reflected in Accrued expenses in the accompanying consolidated balance sheet as of December 31, 2012. In connection with the sale of the BM Interests in 2013, the buyer assumed any liability we may have had related to this matter.
	We and our oil and gas joint interest owners are subject to periodic audits of the joint interest accounts for leases in which we participate and/or operate. As a result of these joint interest audits, amounts payable or receivable by us for costs incurred or revenue distributed by the operator or by us on a lease may be adjusted, resulting in adjustments, increases or decreases, to our net costs or revenues and the related cash flows. Such adjustments may be material. When they occur, these adjustments are recorded in the current period, which generally is one or more years after the related cost or revenue was incurred or recognized by the joint account.

Related_Party_Transactions

Related Party Transactions	1 Months Ended
	Jun. 30, 2014
Related Parties [Abstract]	'
Related Parties	'
	(15) Related Party Transactions
	On June 3, 2014 we acquired from Energy XXI GOM the SP49 Interests located in the Gulf of Mexico for $230.0 million, subject to customary adjustments to reflect an economic effective date of June 1, 2014.  As a result of the SP49 Acquisition, we have become the sole working interest owner of the South Pass 49 field. We financed the SP49 Acquisition with borrowings of approximately $135 million under our Prior Senior Credit Facility and a $95 million capital contribution from EGC.  See Note 3, “Acquisitions and Dispositions” for more information.

Comparative_Period_Information

Comparative Period Information	1 Months Ended
	Jun. 30, 2014
Comparative Period Information [Abstract]	'
Comparative Period Information	'
	(16) Comparative Period Information
	The following tables present certain financial information for the six months ended June 30, 2014 and 2013, respectively.  As more fully described in Note 1, “Organization and Summary of Significant Accounting Policies – Basis of Presentation,” due to our new basis of accounting resulting from the Merger, financial information for periods prior to the Merger is not comparable to such information for periods subsequent to the Merger.
		Period from		Period from		Six Months Ended June 30,
		4-Jun-14		1-Jan-14
		through		through
		June 30,		June 3,
		2014		2014		2013 (Unaudited)
		(in thousands)		(in thousands)
	Total revenue	$	60,143	$	276,400	$	366,436
	Income from operations		13,834		23,563		158,244
	Income (loss) before income taxes		10,211		-18,461		155,057
	Deferred income tax expense		-3,574		-4,495		-56,441
	Net income (loss)	$	6,637	$	-22,956	$	98,616
	Basic earnings (loss) per share			$	-0.59	$	2.51
	Diluted earnings (loss) per share			$	-0.59	$	2.48
	Weighted average common shares used in computing
	earnings (loss) per share:
	Basic				38,730		38,847
	Diluted				38,730		39,302
		Period from		Period from		Six Months Ended June 30,
		4-Jun-14		1-Jan-14
		through		through
		June 30,		June 3,
		2014		2014		2013 (Unaudited)
		(in thousands)		(in thousands)
	Net cash provided by operating activities	$	22,209	$	105,122	$	192,476
	Net cash used in investing activities		-200,929		-258,714		-154,969
	Net cash provided by (used in) financing activities		-15,729		344,830		-35,143
	Net increase (decrease) in cash and cash equivalents		-194,449		191,238		2,364
	Cash and cash equivalents at beginning of period		200,050		8,812		1,521
	Cash and cash equivalents at end of period	$	5,601	$	200,050	$	3,885

Interim_Financial_Information

Interim Financial Information	1 Months Ended
	Jun. 30, 2014
Interim Financial Information [Abstract]	'
Interim Financial Information	'
	(17) Interim Financial Information (Unaudited)
	The following tables summarize our consolidated unaudited interim financial information for the six months ended June 30, 2014 and the year ended December 31, 2013.
			Three		Period from April 1 through			Period from June 4 through
			Months Ended
			March 31 (1)		June 3 (2)			30-Jun
			(In thousands, except per share data)					(In thousands)
	2014
	Revenues		$	159,491	$	116,909			60,143
	Costs and expenses			112,095		140,742			46,309
	Income (loss) from operations			47,396		-23,833			13,834
	Net income (loss)			13,331		-36,287			6,637
	Earnings (loss) per share:
	Basic		$	0.34	$	-0.94
	Diluted			0.34		-0.94
		-1		Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.
		-2		Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.
			Three Months Ended
			31-Mar		30-Jun		September 30(1)			December 31(2)
			(In thousands, except per share data)
	2013
	Revenues		$	182,349	$	184,087	$	183,992		$	142,610
	Costs and expenses			109,657		98,535		143,178			122,077
	Income from operations			72,692		85,552		40,814			20,533
	Net income (loss)			29,037		69,579		-1,284			-12,058
	Earnings (loss) per share:
	Basic		$	0.74	$	1.77	$	-0.03		$	-0.31
	Diluted			0.73		1.75		-0.03			-0.31
	(1)  Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.
	(2)  The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.

Supplementary_Oil_and_Natural_

Supplementary Oil and Natural Gas Disclosures	1 Months Ended
	Jun. 30, 2014
Supplementary Oil and Natural Gas Disclosures [Abstract]	'
Supplementary Oil and Natural Gas Disclosures	'
	(18) Supplementary Oil and Natural Gas Disclosures—(Unaudited)
	Our estimates of proved reserves are based on a reserve report prepared as of June 30, 2014 by the independent petroleum engineering firm Netherland, Sewell & Associates, Inc. Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” natural gas and crude oil reserves is very complex, requiring significant professional judgment in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the professional judgment required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. Proved reserves are estimated quantities of natural gas, crude oil and condensate that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.
	The following table sets forth our estimated net proved reserves, changes in our estimated net proved reserves and our net proved developed and undeveloped reserves.
			Oil		Gas		Oil Equivalent
			(Mbbls)		(Mmcf)		(Mboe)
	Estimated Proved Reserves:
	31-Dec-11			27,301		58,785		37,099
	Acquisitions (a)			16,430		115,876		35,742
	Extensions and discoveries (b)			6,388		10,241		8,095
	Revisions			1,128		4,033		1,800
	Production			-3,805		-8,996		-5,304
	31-Dec-12			47,442		179,939		77,432
	Acquisitions			366		209		401
	Sales			-1,415		-916		-1,568
	Extensions and discoveries (c)			7,354		20,247		10,729
	Revisions			3,952		-10,128		2,264
	Production			-6,182		-15,767		-8,810
	31-Dec-13			51,517		173,584		80,448
	Acquisitions (d)			11,640		32,731		17,095
	Extensions and discoveries (e)			418		5,352		1,310
	Revisions (f)			386		-34,791		-5,413
	Production			-3,129		-4,795		-3,928
	30-Jun-14			60,832		172,081		89,512
	Proved developed reserves:
	31-Dec-12			37,908		120,687		58,022
	31-Dec-13			39,439		107,687		57,387
	30-Jun-14			45,232		101,361		62,126
	Proved undeveloped reserves:
	31-Dec-12			9,534		59,252		19,409
	31-Dec-13			12,078		65,897		23,061
	30-Jun-14			15,600		70,720		27,386
	(a)Reserves acquired in the acquisitions of the Hilcorp Properties and the ST41 Interests.
	(b)Includes extensions and discoveries across 6 different fields, primarily within our West Delta and Ship Shoal areas.  These extensions and discoveries added volumes ranging from 18 Mboe to 1.2 Mmboe each, with three exceeding 1.0 Mmboe each.
	(c)Includes extensions and discoveries across 12 different fields, primarily within our Ship Shoal and West Delta areas.  The Ship Shoal 208 field accounts for 46% of our total extensions and discoveries with 4,973 Mboe, consisting of 3,967 Mbbls of oil and 6,035 Mmcf of produced gas.  The remaining 11 locations account for up to 16% each of total extensions and discoveries with reserves ranging from 10 Mboe to 1.6 Mmboe.
	(d)  Reserves acquired in the acquisitions of the EI Interests and the SP49 Interests.
	(e) Includes extensions and discoveries across 3 different fields, primarily within our West Delta, Ship Shoal and Eugene Island areas.  The West Delta field accounts for 68% of our total extensions and discoveries with 890 Mboe, consisting of 50 Mbbls of oil and 5,040 Mmcf of natural gas.  The Ship Shoal 208 field accounts for approximately 23% of our total extensions and discoveries with 295 Mboe, consisting of 260 Mbbls of oil and 212 Mmcf of natural gas.
	(f)  Natural gas revisions also include negative revisions of approximately 35,976 Mmcf related to the exclusion of estimated fuel gas in our natural gas reserves in the June 30, 2014 reserve volumes. This change in methodology reflects fuel gas as negative natural gas reserves rather than a production cost and does not impact future net cash flows after income taxes or standardized measure of discounted future net cash flows. The negative revisions related to this change in the fuel gas methodology were partially offset by increases of approximately 1,185 Mmcf associated with improved performance of certain wells.
	Capitalized costs for oil and natural gas producing activities consist of the following:
			June 30,
			2014
			(In thousands)
	Proved properties		$	2,316,306
	Unevaluated properties			908,483
	Accumulated depreciation, depletion and amortization			-22,689
	Net capitalized costs		$	3,202,100
			2013
			(In thousands)
	Proved properties		$	2,307,891
	Unproved properties			39,191
	Accumulated depreciation, depletion and amortization			-614,068
	Net capitalized costs		$	1,733,014
	The following table sets forth the costs incurred associated with finding, acquiring and developing our proved oil and natural gas reserves.
			Six Months Ended		Year Ended December 31,
			June 30,
			2014		2013		2012		2011
			(In thousands)
	Acquisitions—Proved (1)		$	314,169	$	46,047	$	706,322	$	261,812
	Acquisitions—Unproved			9,503		2,200		7,496		14
	Exploration			56,079		46,100		43,338		17,129
	Development (2)			242,217		303,245		180,938		83,577
	Costs incurred		$	621,968	$	397,592	$	938,094	$	362,532
	(1)For the six months ended June 30, 2014, includes $231 million associated with the acquisition of the SP 49 Interests and $83 million associated with the acquisition of the EI Interests.  See Note 3 “Acquisitions and Dispositions” of the consolidated financial statements in Part II, Item 8 of this Transition Report for further information.
	(2)Includes our estimates during the years ended December 31, 2013, 2012 and 2011 of incurred asset retirement obligations associated with finding and developing our proved oil and natural gas reserves of $1.2 million, $1.2 million and $0.2 million, respectively.
Expenditures incurred for exploratory dry holes are included in investing activities in the consolidated statements of cash flows.
Standardized Measure of Discounted Future Net Cash Flows Relating to Reserves
The following information has been developed utilizing procedures prescribed by ASC 932. It may be useful for certain comparative purposes, but should not be solely relied upon in evaluating our performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of our oil and natural gas reserves or the current value of the Company.
We believe that the following factors should be taken into account in reviewing the following information: (1) future costs and sales prices are likely to differ materially from those required to be used in these calculations; (2) due to future market conditions, governmental regulations and other factors, actual rates of production achieved in future years may vary significantly from the rate of production assumed in the calculations; (3) the use of a 10% discount rate, while mandated under ASC 932, is arbitrary and may not be reasonable as a measure of the relative risk inherent in realizing future net oil and gas revenues; and (4) future net revenues may be subject to different rates of income taxation.
The Standardized Measure of Discounted Future Net Cash Flows uses future cash inflows estimated using oil and natural gas prices computed by applying the use of physical pricing based on the simple average of the closing price on the first day of each of the twelve months during the fiscal year (as required by ASC 932) and by applying historical adjustments, including transportation, quality differentials, and purchaser bonuses, on an individual property basis, to the year-end quantities of estimated proved reserves. The historical adjustments applied to the computed prices are determined by comparing our historical realized price experience with the comparable historical market, or posted, price. These adjustments can vary significantly over time both in amount and as a percentage of the posted price, especially related to our oil prices during periods when the market price for oil varies widely. The price adjustments reflected in our computed reserve prices may not represent the amount of price adjustments we may actually obtain in the future when we sell our production, nor do they give effect to any hedging transactions that we may enter into.  Future cash inflows were reduced by estimated future development, abandonment and production costs based on period-end costs with the assumption of the continuation of existing economic conditions in order to arrive at net cash flows before tax. Future income tax expense has been computed by applying period-end statutory tax rates to aggregate future net cash flows, reduced by the tax basis of the properties involved and tax carryforwards. Use of a 10% annual discount rate in computing Standardized Measure of Discounted Future Net Cash Flows is required by ASC 932.
The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves is as follows:
				December 31,
		June 30,
		2014		2013
		(In thousands)
Future cash inflows		$	6,704,859	$	5,937,536
Future production costs			-2,126,110		-1,957,868
Future development costs (1)			-1,161,289		-1,085,440
Future income taxes			-712,700		-641,536
Future net cash flows after income taxes			2,704,760		2,252,692
10% annual discount for estimated timing of cash flows			-740,167		-603,614
Standardized measure of discounted future net cash flows		$	1,964,593	$	1,649,078
	-1		Future development cost as of June 30, 2014 include $558.4 million of estimated abandonment and decommissioning costs, net of $120.5 million of estimated salvage values.  Future development costs as of December 31, 2013, include $569.9 million of estimated abandonment and decommissioning costs, net of $25.8 million of estimated salvage values.
A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and natural gas reserves for the six months ended June 30, 2014 and the year ended December 31, 2013 is as follows:
		Six Months Ended		Year Ended
		June 30,		December 31,
		2014		2013
		(In thousands)
Beginning of the period		$	1,649,078	$	1,574,282
Sales and transfers of oil and natural gas produced, net of production costs			-240,361		-513,906
Net changes in prices and production costs (1)			-21,599		96,751
Purchase of minerals in place			471,329		26,708
Sales of minerals in place			-		-64,539
Extensions, discoveries and improved recoveries, net of future production costs			49,566		363,493
Revision of quantity estimates			-325,294		84,490
Previously estimated development costs incurred during the period			55,888		33,920
Changes in estimated future development costs			1,560		18,229
Changes in production rates (timing) and other			170,915		-113,022
Accretion of discount			210,932		197,927
Net change in income taxes			-57,421		-55,255
Net increase			315,515		74,796
End of period		$	1,964,593	$	1,649,078
(1)     Our estimated future production costs reflect a decrease related to the previously described change in the fuel gas  methodology to reflect the fuel gas as negative natural gas reserves rather than production cost.
At June 30, 2014 and December 31, 2013, the computation of the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves was based on the following computed prices:
		2014		2013
per barrel of oil		$	98.58	$	105.30
per Mcf for natural gas		$	4.12	$	3.73

Supplemental_Condensed_Consoli

Supplemental Condensed Consolidating Financial Information	1 Months Ended
	Jun. 30, 2014
Supplemental Condensed Consolidating Financial Information [Abstract]	'
Supplemental Condensed Consolidating Financial Information	'
	(19) Supplemental Condensed Consolidating Financial Information
	In connection with issuing the 8.25% Senior Notes described in Note 8, all of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries) each of which is 100% owned by EPL (the “Guarantor Subsidiaries”) jointly and severally guaranteed the payment obligations under our 8.25% Senior Notes. The guarantees are full and unconditional, as those terms are used in Rule 3-10 of Regulation S-X, except that a Guarantor Subsidiary can be automatically released and relieved of its obligations under certain customary circumstances contained in the 2011 Indenture.  So long as other applicable provisions of the indenture are adhered to, these customary circumstances include: when a Guarantor Subsidiary is declared “unrestricted” for covenant purposes, when the requirements for legal defeasance or covenant defeasance or to discharge the indenture have been satisfied, or when the Guarantor Subsidiary is sold or sells all of its assets. The following supplemental financial information sets forth, on a consolidating basis, the balance sheets, statements of operations and cash flow information for EPL (Parent Company Only) and for the Guarantor Subsidiaries. We have not presented separate financial statements and other disclosures concerning the Guarantor Subsidiaries, or for any individual Guarantor Subsidiary, because management has determined that such information is not material to investors.
	The supplemental condensed consolidating financial information has been prepared pursuant to the rules and regulations for condensed financial information and does not include all disclosures included in annual financial statements. Certain reclassifications were made to conform all of the financial information to the financial presentation on a consolidated basis. The principal eliminating entries eliminate investments in subsidiaries, intercompany balances and intercompany revenues and expenses.
	SUCCESSOR COMPANY
	Supplemental Condensed Consolidating Balance Sheet
	As of June 30, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	5,601	$	-	$	-	$	5,601
	Trade accounts receivable - net		72,156		145		-		72,301
	Intercompany receivables		-		26,311		-26,311		-
	Fair value of commodity derivative instruments		-		-		-		-
	Deferred tax asset		24,587		-		-		24,587
	Prepaid expenses		26,521		-		-		26,521
	Total current assets		128,865		26,456		-26,311		129,010
	Net property and equipment		3,034,805		170,382		-		3,205,187
	Investment in affiliates		126,638		-		-126,638		-
	Goodwill		327,235		-		-		327,235
	Restricted cash		6,023		-		-		6,023
	Fair value of commodity derivative instruments		-		-		-		-
	Deferred financing costs		-		-		-		-
	Other assets		226		91		-		317
	Total assets	$	3,623,792	$	196,929	$	-152,949	$	3,667,772
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	90,267	$	656	$	-	$	90,923
	Intercompany payables		26,311		-		-26,311		-
	Accrued expenses		161,503		15		-		161,518
	Asset retirement obligations		33,357		6,474		-		39,831
	Fair value of commodity derivative instruments		26,440		-		-		26,440
	Due to EGC		4,960		-		-		4,960
	Total current liabilities		342,838		7,145		-26,311		323,672
	Long-term debt		1,025,566		-		-		1,025,566
	Asset retirement obligations		193,908		38,956		-		232,864
	Deferred tax liabilities		459,608		24,190		-		483,798
	Fair value of commodity derivative instruments		2,140		-		-		2,140
	Other		6		-		-		6
	Total liabilities		2,024,066		70,291		-26,311		2,068,046
	Stockholders’ equity:
	Preferred stock		-		-		-		-
	Common stock		-		-		-		-
	Additional paid-in capital		1,599,341		85,479		-85,479		1,599,341
	Accumulated other comprehensive income		-6,252		-		-		-6,252
	Treasury stock, at cost		-		-		-		-
	Retained earnings		6,637		41,159		-41,159		6,637
	Total stockholders’ equity		1,599,726		126,638		-126,638		1,599,726
	Total liabilities and stockholders' equity	$	3,623,792	$	196,929	$	-152,949	$	3,667,772
	PREDECESSOR COMPANY
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	8,812	$	-	$	-	$	8,812
	Trade accounts receivable - net		70,520		187		-		70,707
	Intercompany receivables		39,085		-		-39,085		-
Fair value of commodity derivative instruments		501		-				501
Deferred tax asset		8,949		-		-		8,949
Prepaid expenses		6,868		-				6,868
Total current assets		134,735		187		-39,085		95,837
Net property and equipment		1,514,953		221,478		-		1,736,431
Investment in affiliates		122,697		-		-122,697		-
Deposit for Nexen Acquisition		7,040		-		-		7,040
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		238		-		-		238
Deferred financing costs		10,106		-		-		10,106
Other assets		2,067		89		-		2,156
Total assets	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	58,758	$	673	$	-	$	59,431
Intercompany payables		-		39,085		-39,085		-
Accrued expenses		131,111		14		-		131,125
Asset retirement obligations		51,601		-		-		51,601
Fair value of commodity derivative instruments		29,636		-		-		29,636
Total current liabilities		271,106		39,772		-39,085		271,793
Long-term debt		627,355		-		-		627,355
Asset retirement obligations		160,466		43,383		-		203,849
Deferred tax liabilities		106,910		15,902		-		122,812
Fair value of commodity derivative instruments		2,136		-		-		2,136
Other		673		-		-		673
Total liabilities		1,168,646		99,057		-39,085		1,228,618
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		41		-		-		41
Additional paid-in capital		519,114		85,479		-85,479		519,114
Treasury stock		-31,157		-		-		-31,157
Retained earnings		141,215		37,218		-37,218		141,215
Total stockholders’ equity		629,213		122,697		-122,697		629,213
Total liabilities and stockholders' equity	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Balance Sheet
As of December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	1,521	$	-	$	-	$	1,521
Trade accounts receivable - net		66,994		997		-		67,991
Intercompany receivables		55,575		-		-55,575		-
Fair value of commodity derivative instruments		3,302		-				3,302
Deferred tax asset		3,322		-		-		3,322
Prepaid expenses		9,873		-				9,873
Total current assets		140,587		997		-55,575		86,009
Net property and equipment		1,400,768		197,299		-		1,598,067
Investment in affiliates		111,191		-		-111,191		-
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		211		-		-		211
Deferred financing costs		12,386		-		-		12,386
Other assets		2,841		90		-		2,931
Total assets	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	34,740	$	32	$	-	$	34,772
Intercompany payables		-		55,575		-55,575		-
Accrued expenses		117,245		127		-		117,372
Asset retirement obligations		23,982		6,197		-		30,179
Fair value of commodity derivative instruments		10,026		-		-		10,026
Total current liabilities		185,993		61,931		-55,575		192,349
Long-term debt		689,911		-		-		689,911
Asset retirement obligations		187,790		17,141		-		204,931
Deferred tax liabilities		59,571		8,123		-		67,694
Fair value of commodity derivative instruments		3,637		-		-		3,637
Other		1,132						1,132
Total liabilities		1,128,034		87,195		-55,575		1,159,654
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		40		-		-		40
Additional paid-in capital		510,469		85,479		-85,479		510,469
Treasury stock		-20,477		-		-		-20,477
Retained earnings		55,941		25,712		-25,712		55,941
Total stockholders’ equity		545,973		111,191		-111,191		545,973
Total liabilities and stockholders' equity	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
SUCCESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Period from June 4, 2014 through June 30, 2014
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	53,860	$	5,951	$	-	$	59,811
Other		114		218		-		332
Total revenue		53,974		6,169		-		60,143
Costs and expenses:
Lease operating		15,282		2,464		-		17,746
Transportation		299		-		-		299
Exploration expenditures and dry hole costs		-		-		-		-
Impairments		-		-		-		-
Depreciation, depletion and  amortization		20,950		1,825		-		22,775
Accretion of liability for asset retirement obligations		1,602		420		-		2,022
General and administrative		2,605		12		-		2,617
Taxes, other than on earnings		35		815		-		850
Gain on sale of assets		-		-		-		-
Other		-		-		-		-
Total costs and expenses		40,773		5,536		-		46,309
Income from operations		13,201		633		-		13,834
Other income (expense):
Interest income		4		-		-		4
Interest expense		-3,627		-		-		-3,627
Loss on derivative instruments		-		-		-		-
Income from equity investments		412		-		-412		-
Total other income (expense)		-3,211		-		-412		-3,623
Income before provision for income taxes		9,990		633		-412		10,211
Deferred income tax expense		-3,353		-221		-		-3,574
Net income	$	6,637	$	412	$	-412	$	6,637
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Period from January 1, 2014 through June 3, 2014
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	245,684	$	29,088	$	-	$	274,772
Other		399		1,229		-		1,628
Total revenue		246,083		30,317		-		276,400
Costs and expenses:
Lease operating		62,116		10,186		-		72,302
Transportation		1,474		1		-		1,475
Exploration expenditures and dry hole costs		26,345		-106		-		26,239
Impairments		61		-		-		61
Depreciation, depletion and  amortization		76,481		8,646		-		85,127
Accretion of liability for asset retirement obligations		9,736		2,035		-		11,771
General and administrative		51,434		-		-		51,434
Taxes, other than on earnings		377		4,007		-		4,384
Other		44		-		-		44
Total costs and expenses		228,068		24,769		-		252,837
Income from operations		18,015		5,548		-		23,563
Other income (expense):
Interest income		17		-		-		17
Interest expense		-22,621		-		-		-22,621
Loss on derivative instruments		-19,420		-		-		-19,420
Income from equity investments		3,529		-		-3,529		-
Total other income (expense)		-38,495		-		-3,529		-42,024
Income (loss) before provision for income taxes		-20,480		5,548		-3,529		-18,461
Deferred income tax expense		-2,476		-2,019		-		-4,495
Net income (loss)	$	-22,956	$	3,529	$	-3,529	$	-22,956
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2013
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	606,743	$	82,000	$	-	$	688,743
Other		689		3,606		-		4,295
Total revenue		607,432		85,606		-		693,038
Costs and expenses:
Lease operating		140,605		25,236		-		165,841
Transportation		3,548		20		-		3,568
Exploration expenditures and dry hole costs		22,265		4,290		-		26,555
Impairments		2,937		-		-		2,937
Depreciation, depletion and  amortization		178,427		21,932		-		200,359
Accretion of liability for asset retirement obligations		23,196		5,103		-		28,299
General and administrative		28,137		-		-		28,137
Taxes, other than on earnings		1,084		10,406		-		11,490
Gain on sale of assets		-28,219		-462				-28,681
Other		34,072		870		-		34,942
Total costs and expenses		406,052		67,395		-		473,447
Income from operations		201,380		18,211		-		219,591
Other income (expense):
Interest income		99		-		-		99
Interest expense		-52,368		-		-		-52,368
Gain on derivative instruments		-32,361		-		-		-32,361
Income from equity investments		11,506		-		-11,506		-
Total other income (expense)		-73,124		-		-11,506		-84,630
Income before provision for income taxes		128,256		18,211		-11,506		134,961
Deferred income tax expense		-42,982		-6,705		-		-49,687
Net income	$	85,274	$	11,506	$	-11,506	$	85,274
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	318,749	$	103,780	$	-	$	422,529
Other		15,152		952		-15,000		1,104
Total revenue		333,901		104,732		-15,000		423,633
Costs and expenses:
Lease operating		71,002		23,848		-		94,850
Transportation		611		4		-		615
Exploration expenditures and dry hole costs		18,790		9		-		18,799
Impairments		8,883		-		-		8,883
Depreciation, depletion and  amortization		92,689		20,892		-		113,581
Accretion of liability for asset retirement obligations		10,551		5,014		-		15,565
General and administrative		22,845		15,363		-15,000		23,208
Taxes, other than on earnings		1,162		11,845		-		13,007
Other		5,496		-818		-		4,678
Total costs and expenses		232,029		76,157		-15,000		293,186
Income from operations		101,872		28,575		-		130,447
Other income (expense):
Interest income		136		-		-		136
Interest expense		-28,568		-		-		-28,568
Gain on derivative instruments		-13,305		-		-		-13,305
Income from equity investments		18,945		-		-18,945		-
Total other income (expense)		-22,792		-		-18,945		-41,737
Income before provision for income taxes		79,080		28,575		-18,945		88,710
Deferred income tax expense		-20,270		-9,630		-		-29,900
Net income	$	58,810	$	18,945	$	-18,945	$	58,810
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	245,567	$	102,640	$	-	$	348,207
Other		15,007		113		-15,000		120
Total revenue		260,574		102,753		-15,000		348,327
Costs and expenses:
Lease operating		51,618		18,663		-		70,281
Transportation		766		13		-		779
Exploration expenditures and dry hole costs		14,045		223		-		14,268
Impairments		32,532		-66		-		32,466
Depreciation, depletion and  amortization		82,168		22,456		-		104,624
Accretion of liability for asset retirement obligations		9,013		6,929		-		15,942
General and administrative		18,281		15,460		-15,000		18,741
Taxes, other than on earnings		-733		15,098		-		14,365
Other		9,940		-205		-		9,735
Total costs and expenses		217,630		78,571		-15,000		281,201
Income from operations		42,944		24,182		-		67,126
Other income (expense):
Interest income		102		-		-		102
Interest expense		-17,548		-		-		-17,548
Loss on derivative instruments		-5,870		-		-		-5,870
Loss on early extinguishment of debt		-2,377		-		-		-2,377
Loss from equity investments		15,532		-		-15,532		-
Total other income (expense)		-10,161		-		-15,532		-25,693
Income before provision for income taxes		32,783		24,182		-15,532		41,433
Deferred income tax expense		-6,172		-8,650		-		-14,822
Net income	$	26,611	$	15,532	$	-15,532	$	26,611
SUCCESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Period from June 4, 2014 to June 30, 2014
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	22,163	$	46	$	-	$	22,209
Cash flows provided by (used in) investing activities:
Property acquisitions		-141,886		-		-		-141,886
Exploration and development expenditures		-58,930		-46		-		-58,976
Other property and equipment additions		-67		-		-		-67
Net cash used in investing activities		-200,883		-46		-		-200,929
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		475,000		-		-		475,000
Repayments of indebtedness		-475,000		-		-		-475,000
Advances to EGC		-15,729		-		-		-15,729
Net cash used in financing activities		-15,729		-		-		-15,729
Net decrease in cash and cash equivalents		-194,449		-		-		-194,449
Cash and cash equivalents at beginning of period		200,050		-		-		200,050
Cash and cash equivalents at end of period	$	5,601	$	-	$	-	$	5,601
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Period from January 1, 2014 through June 3, 2014
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	102,307	$	2,815	$	-	$	105,122
Cash flows provided by (used in) investing activities:
Property acquisitions		-57,680		-2,815		-		-60,495
Deposit for Nexen Acquisition		-		-		-		-
Exploration and development expenditures		-197,968		-		-		-197,968
Other property and equipment additions		-251		-		-		-251
Proceeds from sale of assets		-		-		-		-
Net cash used in investing activities		-255,899		-2,815		-		-258,714
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		345,000		-		-		345,000
Repayments of indebtedness		-		-		-		-
Advances to EGC		-						-
Deferred financing costs		-170		-		-		-170
Purchase of shares into treasury		-		-		-		-
Exercise of stock options		-		-		-		-
Net cash provided by financing activities		344,830		-		-		344,830
Net increase in cash and cash equivalents		191,238		-		-		191,238
Cash and cash equivalents at beginning of period		8,812		-		-		8,812
Cash and cash equivalents at end of period	$	200,050	$	-	$	-	$	200,050
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2013
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	356,597	$	30,962	$	-	$	387,559
Cash flows provided by (used in) investing activities:
Property acquisitions		-27,560		-		-		-27,560
Deposit for Nexen		-7,040		-		-		-7,040
Exploration and development expenditures		-284,073		-37,967		-		-322,040
Other property and equipment additions		-2,016		-		-		-2,016
Proceeds from sale of assets		45,312		7,005		-		52,317
Net cash used in investing activities		-275,377		-30,962		-		-306,339
Cash flows provided by (used in) financing activities:
Repayments of indebtedness		-65,000		-		-		-65,000
Deferred financing costs		-674		-		-		-674
Purchase of shares into treasury		-9,640		-		-		-9,640
Exercise of stock options		1,385		-		-		1,385
Net cash used in financing activities		-73,929		-		-		-73,929
Net increase in cash and cash equivalents		7,291		-		-		7,291
Cash and cash equivalents at beginning of period		1,521		-		-		1,521
Cash and cash equivalents at end of period	$	8,812	$	-	$	-	$	8,812
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	190,851	$	23,020	$	-	$	213,871
Cash flows provided by (used in) investing activities:
Property acquisitions		-575,372		-3,000		-		-578,372
Exploration and development expenditures		-165,308		-19,542		-		-184,850
Other property and equipment additions		-1,265		-478		-		-1,743
Net cash used in investing activities		-741,945		-23,020		-		-764,965
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		509,313		-		-		509,313
Repayments of indebtedness		-20,000		-		-		-20,000
Deferred financing costs		-8,469		-		-		-8,469
Purchase of shares into treasury		-8,798		-		-		-8,798
Exercise of stock options		441		-		-		441
Net cash provided by financing activities		472,487		-		-		472,487
Net decrease in cash and cash equivalents		-78,607		-		-		-78,607
Cash and cash equivalents at beginning of period		80,128		-		-		80,128
Cash and cash equivalents at end of period	$	1,521	$	-	$	-	$	1,521
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	136,245	$	35,007	$	-	$	171,252
Cash flows provided by (used in) investing activities:
Decrease in restricted cash		2,466		-		-		2,466
Property acquisitions		-235,486		-		-		-235,486
Exploration and development expenditures		-40,996		-35,007		-		-76,003
Other property and equipment additions		-1,568		-		-		-1,568
Net cash used in investing activities		-275,584		-35,007		-		-310,591
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		203,794		-		-		203,794
Deferred financing costs		-6,646		-		-		-6,646
Purchase of shares into treasury		-11,353		-		-		-11,353
Exercise of stock options		119		-		-		119
Net cash provided by financing activities		185,914		-		-		185,914
Net increase in cash and cash equivalents		46,575		-		-		46,575
Cash and cash equivalents at beginning of period		33,553		-		-		33,553
Cash and cash equivalents at end of period	$	80,128	$	-	$	-	$	80,128

Organization_and_Summary_of_Si1

Organization and Summary of Significant Accounting Policies (Policy)	1 Months Ended
	Jun. 30, 2014
Organization and Summary of Significant Accounting Policies [Abstract]	'
Basis of Presentation	'
	(a) Basis of Presentation
	The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of EPL and our wholly-owned subsidiaries. All significant intercompany accounts and transactions are eliminated in consolidation. Our interests in oil and natural gas exploration and production ventures and partnerships are proportionately consolidated.
	The Merger resulted in EPL becoming an indirect, wholly owned subsidiary of Energy XXI.  Therefore, in the preparation of our financial statements, we have applied “pushdown” accounting, based on guidance from the Securities and Exchange Commission (“SEC”).  Pushdown accounting refers to the use of the acquiring entity’s basis of accounting in the preparation of the acquired entity’s financial statements.  As a result, our separate financial statements reflect the new basis of accounting recorded by the Energy XXI upon acquisition.  As such, in accordance with GAAP, due to our new basis of accounting, our financial statements include a black line denoting that our financial statements covering periods prior to the date of the Merger are not comparable to our financial statements as of and subsequent to the date of the Merger.  References to the “Predecessor Company” refer to reporting dates of the Company through June 3, 2014, reflecting results of operations and cash flows of the Company prior to the Merger on our historical accounting basis; subsequent thereto, the Company is referred to as the “Successor Company,” reflecting the impact of pushdown accounting and the results of operations and cash flows of the Company subsequent to the Merger. See Note 2, “Pushdown Accounting” for more information regarding these transactions.
	Energy XXI follows the “full cost” method of accounting for its oil and gas producing activities, while we had historically followed the “successful efforts” method of accounting. Subsequent to the Merger, we converted our accounting method from successful efforts to the full cost method of accounting to be consistent with Energy XXI’s method of accounting pursuant to SEC guidance, which requires a reporting entity that follows the full cost method to apply that method to all of its operations and to the operations of its subsidiaries. Under GAAP, a change in accounting method is required to be applied retroactively in order to provide comparable historical period information to users of financial statements. However, due to the new basis of accounting established as a result of the Merger transaction and pushdown accounting, our financial statements are no longer comparable to those of prior periods and we have applied the full cost method of accounting on a prospective basis from the date of the Merger.
	Energy XXI has a fiscal year end of June 30, while we historically had a fiscal year end of December 31. Subsequent to the Merger, we changed our year end to June 30 to be consistent with Energy XXI.  Therefore, these financial statements include audited statements of operations, cash flows and stockholders’ equity using the successful efforts method of accounting applied to our historical basis in our assets and liabilities for the five months and three days ended June 3, 2014 and audited statements of operations, cash flows and stockholders’ equity using the full cost method of accounting applied to EPL’s new basis in its assets and liabilities established in the Merger transaction for the twenty-seven days ended June 30, 2014, with a black line between the periods denoting that they are not comparable.
Oil and Natural Gas Property and Equipment	'
	(b) Oil and Natural Gas Property and Equipment
	Prior to the Merger, we used the successful efforts method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and complete exploratory wells that find proved reserves, and to drill and complete development wells are capitalized. Exploratory drilling costs were initially capitalized, but charged to expense if and when the well is determined not to have found reserves in commercial quantities. We may have capitalized exploratory well costs beyond one year if (a) we found a sufficient quantity of reserves to justify its completion as a producing well and (b) we were making sufficient progress assessing the reserves and the economic and operating viability of the project; otherwise, these costs were expensed. Geological and geophysical costs were charged to expense as incurred.
	Leasehold acquisition costs were capitalized as unproved properties. If proved reserves were discovered on undeveloped leases, the related leasehold costs were transferred to proved properties and amortized using the units of production method. For individual unevaluated properties with capitalized costs below a threshold amount, we allocated capitalized costs to earnings generally over the primary lease terms. Properties that were subject to amortization and those with capitalized costs greater than the threshold amount were assessed for impairment periodically. Capitalized costs of producing oil and natural gas properties were depreciated and depleted by the units-of-production method.
	We evaluated our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicated that the carrying values may not have been recoverable. The need to test a property for impairment was based on several factors, including a significant reduction in sales prices for oil and/or natural gas, unfavorable adjustments to reserve volumes, actual operating and development costs in excess of expected amounts, changes in estimates of future operating and capital expenditure requirements, or other changes to contracts, environmental regulations or tax laws. The calculation was performed on a field-by-field basis, utilizing our current estimates of future revenues and operating expenses. In the event net undiscounted cash flow was less than the carrying value, an impairment loss was recorded based on the present value of expected future net cash flows over the economic lives of the reserves.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion, depreciation and amortization were eliminated from the property accounts, along with the related asset retirement obligations, unless retained by us, and the resulting gain or loss was recognized in earnings.
	As described above, subsequent to the Merger, we adopted the full cost method of accounting for exploration and development activities. Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as properties and equipment. This includes any internal costs that are directly related to property acquisition, exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. Gain or loss on the sale or other disposition of oil and gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves.
	Oil and natural gas properties include costs that are excluded from costs being depleted or amortized. Costs excluded from depletion or amortization represent investments in unevaluated properties and include non-producing leasehold, geological and geophysical costs associated with leasehold or drilling interests and exploration drilling costs. We exclude these costs until the property has been evaluated.  We also allocate a portion of our acquisition costs to unevaluated properties based on fair value.  Costs are transferred to the full cost pool as the properties are evaluated or over the life of the reservoir.
	We evaluate the impairment of our evaluated oil and natural gas properties through the use of a ceiling test as prescribed by SEC Regulation S-X Rule 4-10. Future production volumes from oil and natural gas properties are a significant factor in determining the full cost ceiling limitation of capitalized costs. There are numerous uncertainties inherent in estimating quantities of proved oil and natural gas reserves. Oil and natural gas reserve engineering is a subjective process of estimating underground accumulations of oil and natural gas that cannot be precisely measured. Such cost estimates related to future development costs of proved oil and natural gas reserves could be subject to revisions due to changes in regulatory requirements, technological advances and other factors which are difficult to predict.
Other Property and Equipment	'
	(c) Other Property and Equipment
	Other property and equipment include buildings, data processing and telecommunications equipment, office furniture and equipment, vehicle and leasehold improvements and other fixed assets.  These items are recorded at cost and are depreciated using the straight-line method based on expected lives of the individual assets or group of assets, which ranges from three to five years.  Repairs and maintenance costs are expensed in the period incurred.
Asset Retirement Obligations	'
	(d) Asset Retirement Obligations
	Our investment in oil and natural gas properties includes an estimate of the future cost associated with dismantlement, abandonment and restoration of our properties. The present value of the future costs are added to the capitalized cost of our oil and natural gas properties and recorded as a long-term or current liability. The capitalized cost is included in oil and natural gas properties cost that are depleted over the life of the assets. The estimation of future costs associated with dismantlement, abandonment and restoration requires the use of estimated costs in future periods that, in some cases, will not be incurred until a substantial number of years in the future. Such cost estimates could be subject to revisions in subsequent years due to changes in regulatory requirements, technological advances and other factors which may be difficult to predict.
Income Taxes	'
	(e)  Income Taxes
	We account for income taxes under the asset and liability method, which requires that we recognize deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis amounts. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We recognize the effect on deferred tax assets and liabilities of a change in the tax rates in income in the period that includes the enactment date.
	We follow the provisions of Financial Accounting Standards Board Accounting Standards Codification (“ASC”) Topic 740, “Income Taxes,” which apply to the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements and prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These provisions also contain guidance on de-recognition, classification, interest and penalties. Interest, if any, is classified as a component of interest expense, and statutory penalties, if any, are classified as a component of general and administrative expense.
Deferred Financing Costs	'
	(f) Deferred Financing Costs
	We defer costs incurred to obtain debt financing and then amortize such costs as additional interest expense over the maturity period of the related debt using the effective interest rate method.
Earnings Per Share	'
	(g) Earnings Per Share
	Basic earnings per share is computed by dividing income or loss available to common stockholders by the weighted average number of common shares outstanding during each period. According to GAAP, we have determined that our unvested restricted share awards, which contain non-forfeitable rights to dividends, are participating securities and should be included in the computation of earnings per share pursuant to the “two-class” method. The “two-class” method allocates undistributed earnings between common shares and participating securities. The diluted earnings per share calculation under the “two-class” method also includes the effect, if dilutive, of potential common shares associated with stock option awards outstanding during each period. The dilutive effect of stock options is determined using the treasury stock method.
Revenue Recognition	'
	(h) Revenue Recognition
	We record revenues from the sales of oil and natural gas when the product is delivered at a determinable price, title has transferred and collectability is reasonably assured. When we have an interest with other producers in properties from which natural gas is produced, we use the entitlement method for recording natural gas sales revenue. Under this method of accounting, revenue is recorded based on our net revenue interest in production. Deliveries of natural gas in excess of our revenue interest are recorded as liabilities and under-deliveries are recorded as receivables. We had natural gas imbalance liabilities of $2.0 million, $2.0 million and $1.7 million at June 30, 2014 and December 31, 2013 and 2012, respectively. We had natural gas imbalance receivables of $0.2 million, $1.9 million and $0.8 million at June 30, 2014 and December 31, 2013 and 2012, respectively.
Cash and Cash Equivalents	'
	(i) Cash and Cash Equivalents
	We include in cash and cash equivalents our highly-liquid investments with original maturities of three months or less. At December 31, 2013 and 2012, cash and cash equivalents includes investments in overnight interest-bearing deposits of $7.3 million and $2.3 million, respectively. These amounts are reduced by overdraft balances on other operating accounts with legal right of offset in the same banking institution to arrive at the cash and cash equivalent balances reported in our consolidated balance sheets.
Derivative Activities	'
		(j)	Derivative Activities
	Derivative instruments, including certain derivative instruments embedded in other contracts, are recorded at fair value and included as either assets or liabilities in the consolidated balance sheets. The accounting for changes in fair value depends on the intended use of the derivative and the resulting designation, which is established at the inception of the derivative. Prior to the Merger, we did not elect to designate derivative instruments as hedges. Gains and losses resulting from changes in the fair value of derivative instruments were recorded in other income (expense). Gains and losses related to contract settlements were also recorded in other income (expense).
	Subsequent to the Merger, gains or losses resulting from transactions designated as cash flow hedges, recorded at market value, are deferred and recorded, net of the related tax impact, in Accumulated Other Comprehensive Income (“AOCI”) as appropriate, until recognized as operating income in our consolidated statement of operations as the physical production hedged by the contracts is delivered. Instruments not qualifying for hedge accounting treatment are recorded in the consolidated balance sheets and changes in fair value are recognized directly in earnings.
	The net cash flows related to any recognized gains or losses associated with cash flow hedges are reported as oil and natural gas revenue and presented in cash flow from operations. If a hedge is terminated prior to expected maturity, gains or losses are deferred and included in income in the same period as the physical production hedged by the contract is delivered.
Share-Based Compensation	'
	(k) Share-Based Compensation
	We recognize share-based compensation expense based on the estimated grant-date fair value of all share-based awards, net of an estimated forfeiture rate, over the requisite service period of the awards, which is generally equivalent to the vesting term. We record share-based compensation expense only for those awards expected to vest. We periodically revise our estimated forfeiture rate if actual forfeitures differ from our estimates.  Compensation expense for liability awards is based on the fair value of the vested award at the end of each reporting period.
	We are required to report excess tax benefits from the exercise of stock options as financing cash flows. For the period from January 1, 2014 through June 3, 2014 and the years ended December 31, 2013 and 2012, no excess tax benefits were reported in the statement of cash flows as we were in a net operating loss carryforward position. See Note 12, “Income Taxes,” for additional disclosures.
Accounts Receivable and Allowance for Doubtful Accounts	'
	(l) Accounts Receivable and Allowance for Doubtful Accounts
	Accounts receivable are stated at historical carrying amount net of allowance for doubtful accounts.  We establish provisions for losses on accounts receivable if it is determined that collection of all or a part of an outstanding balance is not probable.  Collectability is reviewed regularly and an allowance is established or adjusted, as necessary, using the specific identification method.   As of June 30, 2014, no allowance for doubtful accounts was necessary.  As of December 31, 2013, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2013.  As of December 31, 2012, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2012.
Accrued Expenses	'
	(m) Accrued Expenses
	As of June 30, 2014, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $127.6 million, other accrued expenses of $18.1 million and interest payable of approximately $15.8 million. As of December 31, 2013, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $107.8 million, other accrued expenses of $7.5 million and interest payable of approximately $15.8 million. As of December 31, 2012, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $ 84.9 million, other accrued expenses of $ 16.3 million and interest payable of approximately $ 16.2 million.
Goodwill	'
	(n) Goodwill
	We recorded goodwill during 2014 as a result of pushdown accounting in conjunction with the Merger.  Goodwill has an indefinite useful life and is not amortized, but rather is tested for impairment at least annually during the fiscal third quarter, unless events occur or circumstances change between annual tests that would more likely than not reduce the fair value of a related reporting unit below its carrying value. Impairment occurs when the carrying amount of goodwill exceeds its implied fair value. Events affecting crude oil and natural gas prices may cause a decrease in the fair value of the reporting unit, and we could have an impairment of goodwill in future periods.
Use of Estimates	'
	(o) Use of Estimates
	The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We use historical experience and various other assumptions that are believed to be reasonable under the circumstances to form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Our actual results may differ from these estimates and assumptions used in preparation of our financial statements. Significant estimates with regard to these financial statements and related unaudited disclosures include the estimate of proved oil and natural gas reserve quantities and the related present value of estimated future net cash flows therefrom disclosed in Note 18, "Supplementary Oil and Natural Gas Disclosures”.
New Accounting Pronouncements	'
	(p) New Accounting Pronouncements
	In May 2014, the FASB issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (ASU 2014-09). ASU 2014-09 provides a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and will supersede most current revenue recognition guidance. The standard is effective for public entities for annual and interim periods beginning after December 15, 2016. Early adoption is not permitted. We are currently evaluating the provisions of ASU 2014-09 and assessing the impact, if any, it may have on our financial position, results of operations or cash flows.
	In August 2014, the FASB issued Accounting Standards Update No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (ASU 2014-15).  ASU 2014-15 requires management to assess an entity’s ability to continue as a going concern, and to provide related footnote disclosures in certain circumstances.  The standard is effective for public entities for annual and interim periods beginning after December 15, 2016, with early adoption permitted. We are currently evaluating the provisions of ASU 2014-15 and assessing the impact, if any, it may have on our financial position, results of operations or cash flows.

Pushdown_Accounting_Tables

Pushdown Accounting (Tables)	1 Months Ended
	Jun. 30, 2014
Pushdown Accounting [Abstract]	'
Schedule of Pushdown Accounting Adjustments on Balance Sheets	'
	The following table reflects the impact on our condensed consolidated balance sheet of the pushdown accounting adjustments required to reflect the fair value of our assets acquired and liabilities assumed by Energy XXI in the Merger:
		PREDECESSOR				SUCCESSOR
		COMPANY				COMPANY
		June 3,		PUSHDOWN		June 3,
		2014		ADJUSTMENTS		2014
	ASSETS
	Current assets:
	Cash and cash equivalents	$	200,050	$	-	$	200,050
	Trade accounts receivable - net		91,813		1,194		93,007
	Deferred tax asset		8,405		16,182		24,587
	Prepaid expenses		9,729		80		9,809
	Total current assets		309,997		17,456		327,453
	Property and equipment, net of accumulated depreciation, depletion and amortization		1,969,382		972,510		2,941,892
	Goodwill		-		327,235		327,235
	Restricted cash		6,023		-		6,023
	Fair value of commodity derivative instruments		27		-		27
	Deferred financing costs		9,002		-9,002		-
	Other assets		1,175		-		1,175
	Total assets	$	2,295,606	$	1,308,199	$	3,603,805
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	61,938	$	-	$	61,938
	Accrued expenses		230,086		-		230,086
	Asset retirement obligations		39,859		3,758		43,617
	Fair value of commodity derivative instruments		22,625		-		22,625
	Total current liabilities		354,508		3,758		358,266
	Long-term debt		973,440		52,967		1,026,407
	Asset retirement obligations		220,302		9,453		229,755
	Deferred tax liabilities		126,764		356,827		483,591
	Fair value of commodity derivative instruments		1,439		-		1,439
	Other		803		-797		6
	Total liabilities		1,677,256		422,208		2,099,464
	Commitments and contingencies
	Stockholders’ equity:
	Preferred stock, par value $0.001 per share.		-		-		-
	Common stock, par value $0.001 per share.		41		-41		-
	Additional paid-in capital		538,844		965,497		1,504,341
	Treasury stock, at cost		-38,794		38,794		-
	Retained earnings		118,259		-118,259		-
	Total stockholders’ equity		618,350		885,991		1,504,341
	Total liabilities and stockholders' equity	$	2,295,606	$	1,308,199	$	3,603,805

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	1 Months Ended
	Jun. 30, 2014
Schedule of Revenues and Leases Operating Expenses Attributable to Acquired Oil and Gas Properties	'
	Revenues and lease operating expenses attributable to acquired interests and properties were as follows:
			Period from			Period from January 1, 2014 through June 3,		Year Ended December 31,
			June 4, 2014 through June 30,
			2014			2014		2013		2012
			(In thousands)			(In thousands)
	SP49 Interests:
	Revenues		$	5,126		$	-	$	-	$	-
	Lease operating expenses		$	600		$	-	$	-	$	-
	EI Interests:
	Revenues		$	4,379		$	17,565	$	-	$	-
	Lease operating expenses		$	1,151		$	7,264	$	-	$	-
	WD29 Interests:
	Revenues		$	1,232		$	5,681	$	3,011	$	-
	Lease operating expenses		$	12		$	89	$	44	$	-
	Hilcorp Properties:
	Revenues		$	22,455		$	100,571	$	208,241	$	37,978
	Lease operating expenses		$	7,489		$	29,189	$	74,404	$	10,982
	ST41 Interests:
	Revenues		$	843		$	3,406	$	11,189	$	9,262
	Lease operating expenses		$	148		$	1,217	$	2,468	$	1,760
Schedule of Consolidated Results of Operations	'
			PRO FORMA
			Period from		Year Ended
			1-Jan-14		December 31,
			through June 3,
			2014		2013
		(in thousands, except per share data)
	Revenue		$	303,742	$	823,436
	Net income (loss)			-15,546		122,391
	Basic earnings (loss) per share			-0.4		3.13
	Diluted earnings (loss) per share			-0.4		3.09
The South Pass 49 [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments of $0.2 million to reflect an economic effective date of June 1, 2014.
	(In thousands)	1-Jun-14
	Oil and natural gas properties	$	231,271
	Asset retirement obligations		-1,086
	Net assets acquired	$	230,185
Nexen Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments of $5.7 million to reflect an economic effective date of September 1, 2013.
	(In thousands)	1-Sep-13
	Oil and natural gas properties	$	82,897
	Asset retirement obligations		-18,165
	Net assets acquired	$	64,732
Non-Operated Bay Marchand Field Disposition [Member]	'
Schedule of Carrying Amount of Net Assets Sold	'
	The following table summarizes the carrying amount of the net assets sold and reflects final adjustments to the sale price provided for by the purchase and sale agreement of approximately $0.7 million to reflect the economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	35,298
	Asset retirement obligations		-3,959
	Other liabilities		-7,311
	Net assets sold	$	24,028
Hilcorp Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $5.7 million to reflect an economic effective date of July 1, 2012.
	(In thousands)	1-Jul-12
	Oil and natural gas properties	$	698,660
	Asset retirement obligations		-150,959
	Net assets acquired	$	547,701
South Timbalier Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $0.4 million to reflect an economic effective date of April 1, 2012.
	(In thousands)	April 1, 2012
	Oil and natural gas properties	$	33,206
	Asset retirement obligations		-1,878
	Net assets acquired	$	31,328
West Delta 29 Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $7.1 million to reflect an economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	16,544
	Asset retirement obligations		-1,398
	Net assets acquired	$	15,146

Earnings_per_Share_Tables

Earnings per Share (Tables)	1 Months Ended
	Jun. 30, 2014
Earnings per Share [Abstract]	'
Basic and Diluted Weighted Average Shares Outstanding and Earnings per Share	'
	The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.
		Period from January 1, 2014		Year Ended December 31,
		through June 3,
		2014		2013		2012		2011
				(in thousands, except per share data)
	Income (numerator):
	Net income (loss)	$	-22,956	$	85,274	$	58,810	$	26,611
	Net income attributable to participating securities		-		-943		-455		-77
	Net income (loss) attributable to common shares	$	-22,956	$	84,331	$	58,355	$	26,534
	Weighted average shares (denominator):
	Weighted average shares—basic		38,730		38,730		38,885		39,946
	Dilutive effect of stock options		-		506		149		104
	Weighted average shares—diluted		38,730		39,236		39,034		40,050
	Basic earnings (loss) per share	$	-0.59	$	2.18	$	1.50	$	0.66
	Diluted earnings (loss) per share	$	-0.59	$	2.15	$	1.50	$	0.66
Number of Antidilutive Shares Excluded from the Computation of Dilutive Weighted Average Shares	'
	The following table indicates the number of shares underlying outstanding stock-based awards excluded from the computation of dilutive weighted average shares because their effect was antidilutive for the periods indicated.
		Period from		Year Ended December 31,
		1-Jan-14
		through June 3,
		2014		2013		2012		2011
		(in thousands)		(in thousands)
	Weighted average shares		941		273		687		442

Property_and_Equipment_Tables

Property and Equipment (Tables)	1 Months Ended
	Jun. 30, 2014
Property and Equipment [Abstract]	'
Property and Equipment	'
	The following table summarizes our property and equipment.
		June 30,
		2014
		(In thousands)
	Proved oil and natural gas properties	$	2,316,306
	Unevaluated oil and natural gas properties		908,483
	Other		3,173
	Less:  accumulated depreciation, depletion and amortization		-22,775
	Total property and equipment, net of accumulated depreciation, depletion and amortization	$	3,205,187
		December 31,
		2013		2012
		(In thousands)
	Proved oil and natural gas properties	$	2,307,891	$	1,982,657
	Unproved oil and natural gas properties		39,191		36,992
	Other		8,137		5,998
	Less:  accumulated depreciation, depletion and amortization		-618,788		-427,580
	Total property and equipment, net of accumulated depreciation, depletion	$	1,736,431	$	1,598,067
	and amortization

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	1 Months Ended
	Jun. 30, 2014
Asset Retirement Obligations [Abstract]	'
Schedule of Changes in Asset Retirement Obligations	'
	The following table reconciles the beginning and ending aggregate recorded amount of our asset retirement obligations (“ARO”).
		Period from		Period from January 1, 2014		Year Ended December 31,		Year Ended December 31,
		June 4, 2014 through June 30,		through June 3,
		2014		2014		2013		2012
		(in thousands)		(in thousands)
	Beginning of period total	$	260,161	$	255,450	$	235,110	$	99,347
	Accretion expense		2,022		11,771		28,299		15,565
	Liabilities assumed in acquisitions		1,086		18,165		23,541		132,109
	Pushdown accounting fair value adjustment		13,213		-		-		-
	Liabilities incurred		-		-		1,187		1,210
	Revisions		-		7,415		24,586		22,308
	Liabilities associated with assets sold		-		-		-3,965		-
	Liabilities settled		-3,787		-32,640		-53,308		-35,429
	End of period total		272,695		260,161		255,450		235,110
	Less: End of period, current portion		-39,831		-39,859		-51,601		-30,179
	End of period, noncurrent portion	$	232,864	$	220,302	$	203,849	$	204,931

Indebtedness_Tables

Indebtedness (Tables)	1 Months Ended
	Jun. 30, 2014
Schedule of Indebtedness	'
	The following table sets forth our indebtedness.
			June 30,		December 31,		December 31,
			2014		2013		2012
			(In thousands)		(In thousands)
	8.25% senior notes due 2018		$	550,566	$	497,355	$	494,911
	Revolving credit sub-facility			475,000		-		-
	Senior credit facility			-		130,000		195,000
	Total indebtedness			1,025,566		627,355		689,911
	Current portion of indebtedness			-		-		-
	Noncurrent portion of indebtedness		$	1,025,566	$	627,355	$	689,911
8.25% Senior Notes [Member]	'
Schedule of Redeemable Debt	'
	On or after February 15, 2015, we may on any one or more occasions redeem all or a part of the 8.25% Senior Notes upon not less than 30 nor more than 60 days’ notice, at the redemption prices (expressed as percentages of principal amount) set forth below, plus accrued and unpaid interest and special interest, if any, on the notes redeemed, to the applicable date, if redeemed during the twelve-month period beginning on February 15 of the years indicated below, subject to the rights of holders of notes on the relevant record date to receive interest on the relevant interest payment date:
	Year	Percentage
	2015	104.125%
	2016	102.063%
	2017 and thereafter	100.000%

Recovered_Sheet1

Derivative Instruments And Hedging Activities (Tables)	1 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Schedule of Derivative Instruments Outstanding	'
	The following tables set forth our derivative instruments outstanding as of June 30, 2014 for periods prior to the Merger.  Prior to the Merger, we did not elect to designate derivative instruments as hedges.
	Oil Contracts
		Fixed-Price Swaps
		Daily Average						Average
		Volume			Volume			Swap Price
	Remaining Contract Term	(Bbls)			(Bbls)			($/Bbl)
	July 2014 - December 2014		8,769			1,613,550			92.84
	January 2015 - December 2015		1,500			547,500			97.70
	Gas Contracts
		Type						Average		Weighted Average Contract Price
										($/Mmbtu)
		of			Volume			Swap Price		Sub
	Remaining Contract Term	Contract			(Mmbtu)			($/Mmbtu)		Floor	Floor	Ceiling
	July 2014 - December 2014		Three-Way Collars			1,257,000				3.25	4.00	4.76
	July 2014 - December 2014		Put Spreads			583,000				3.25	4.00
	July 2014 - December 2014		Fixed Price Swaps			920,000			4.01
	January 2015 - December 2015		Fixed Price Swaps			1,569,500			4.31
Components of Gain (Loss) on Derivative Instruments	'
	The following table presents information about the components of loss on derivative instruments for periods prior to the Merger, during which we did not elect to designate derivative instruments as hedges.
			Period from			Years Ended December 31,
			1-Jan-14
			through
			June 3,
			2014			2013			2012			2011
			(in thousands)
	Change in fair market value		$	6,996		$	-20,884		$	-9,491		$	11,475
	Loss on settlement			-26,416			-11,477			-3,814			-17,345
	Total loss on derivative instruments		$	-19,420		$	-32,361		$	-13,305		$	-5,870

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	1 Months Ended
	Jun. 30, 2014
Fair Value Measurements [Abstract]	'
Schedule of Fair Value Measurements of Assets and Liabilities	'
	The following table sets forth our financial assets and liabilities that are accounted for at fair value on a recurring basis.
		June 30,		December 31,
		2014		2013		2012
		(in thousands)
	Assets:
	Current	$	-	$	501	$	3,302
	Noncurrent		-		238		211
	Total gross fair value		-		739		3,513
	Less: counterparty set-off		-		-739		-3,513
	Total net fair value	$	-	$	-	$	-
	Liabilities:
	Current	$	26,440	$	29,636	$	10,026
	Noncurrent		2,140		2,136		3,637
	Total gross fair value		28,580		31,772		13,663
	Less: counterparty set-off		-		-739		-3,513
	Total net fair value	$	28,580	$	31,033	$	10,150
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	'
	The following table sets forth the carrying values and estimated fair values of our long-term indebtedness.
		30-Jun-14				31-Dec-13				31-Dec-12
		(In thousands)
			Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
	8.25% Senior Notes	$	550,566	$	545,700	$	497,355	$	546,338	$	494,911	$	524,600
	Revolving credit sub-facility		475,000		475,000		-		-		-		-
	Prior Senior Credit Facility		-		-		130,000		130,000		195,000		195,000
	Total	$	1,025,566	$	1,020,700	$	627,355	$	676,338	$	689,911	$	719,600

Income_Taxes_Tables

Income Taxes (Tables)	1 Months Ended
	Jun. 30, 2014
Income Taxes [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	The components of our income tax provision (reflecting pushdown accounting as described in Notes 1 and 2) are as follows (in thousands):
		Period from June 4, 2014 through				Period from			Year Ended December 31,
		June 30,				1-Jan-14
						through
						June 3,
		2014				2014			2013			2012			2011
		(In thousands)				(In thousands)
	Current:
	Federal	$	-			$	-		$	-		$	-		$	-
	State		-				-			-			-			-
	Total current	$	-			$	-		$	-		$	-		$	-
	Deferred:
	Federal	$	-3,574			$	-4,318		$	-47,723		$	-28,719		$	-14,468
	State		-				-177			-1,964			-1,181			-354
	Total deferred	$	-3,574			$	-4,495		$	-49,687		$	-29,900		$	-14,822
	Total:
	Federal	$	-3,574			$	-4,318		$	-47,723		$	-28,719		$	-14,468
	State		-				-177			-1,964			-1,181			-354
	Total provision for income taxes.	$	-3,574			$	-4,495		$	-49,687		$	-29,900		$	-14,822
Schedule of Effective Income Tax Rate (Benefit) Reconciliation	'
	The following is a reconciliation of the statutory federal income tax rate to our effective income tax rate:
		Percentage of Pretax Earnings
		Period from June 4, 2014 through				Period from			Year Ended December 31,
		June 30,				1-Jan-14
						through
						June 3,
		2014				2014			2013			2012			2011
	Statutory federal income tax rate		35.0	%			35.0	%		35.0	%		35.0	%		35.0	%
	State taxes		-				1.4			1.4			1.4			2.3
	Non-deductible items		-				-59.5			-			-			-
	Change in state tax rate		-				-			-			-2.7			-1.7
	Statutory depletion		-				-			-0.3			-0.4			-1
	Other		-				-1.2			0.7			0.4			1.2
	Effective income tax rate		35.0	%			-24.3	%		36.8	%		33.7	%		35.8	%
Schedule of Deferred Tax Assets and Liabilities	'
	The components of our deferred taxes are detailed in the table below (in thousands):
		June 30,			December 31,
		2014			2013			2012
		(In thousands)			(In thousands)
	Deferred tax assets:
	Federal and state net operating loss carryforwards	$	61,546		$	62,015		$	62,130
	Fair value of commodity derivative instruments		12,136			11,578			3,912
	Restricted stock awards and options		-			3,843			2,313
	Percentage depletion carryforward		-			5,003			4,575
	Basis differences in indebtedness		19,651			-			-
	Accruals and other		701			1,130			2,613
	Deferred tax asset		94,034			83,569			75,543
	Deferred tax liabilities:
	Property, plant and equipment, principally due to	$	550,435		$	193,191		$	136,016
	differences in depreciation
	Fair value of commodity derivative instruments		-			182			214
	Prepaid assets		1,663			1,482			1,778
	Accruals and other		1,147			2,577			1,907
	Deferred tax liabilities		553,245			197,432			139,915
	Net deferred tax liability		459,211			113,863			64,372
	Reflected in accompanying balance sheets as:
	Current deferred asset		24,587			8,949			3,322
	Non-current deferred liability		483,798			122,812			67,694
	Total net deferred tax liability	$	459,211		$	113,863		$	64,372

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	1 Months Ended
	Jun. 30, 2014
Employee Benefit Plans [Abstract]	'
Schedule of Share-based Compensation, Stock Options, Activity	'
	The following table sets forth our stock option activity for the period from January 1, 2014 through June 3, 2014.
		Options			Weighted-			Weighted-			Aggregate Intrinsic Value
					Average			Average
					Exercise			Remaining
					Price Per			Contractual
					Share			Terms
								(in years)			(in thousands)
	Outstanding on December 31, 2013		1,453,173		$	17.76
	Granted		143,114			26.79
	Exercised		-1,596,287			18.57
	Outstanding on June 3, 2014		-		$	-			-		$	-
	Exercisable on June 3, 2014		-		$	-			-		$	-
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	'
	The fair value of each stock option award was estimated on the date of grant using the Black-Scholes option valuation model using the weighted average assumptions in the table below.
		Period from				Year Ended December 31,
		1-Jan-14
		through June 3,
		2014				2013			2012			2011
	Black-Scholes option pricing model assumptions:
	Risk free interest rate		2.0	%		1.4	%		1.0	%		1.9	%
	Expected life (years)		6.0			6.0			6.0			6.0
	Expected volatility		57	%		56	%		56	%		53	%
	Dividend yield		-			-			-			-
Schedule of Nonvested Share Activity	'
	The following table sets forth the activity related to our non-vested share awards for the period from January 1, 2014 through June 3, 2014.
		Shares			Weighted-
					Average
					Grant-Date
					Fair Value
	Non-vested share awards outstanding at December 31, 2013		444,495		$	21.98
	Granted		161,370			25.08
	Vested		-605,865			22.81
	Non-vested share awards outstanding at June 3, 2014		-
Schedule of Share-Based Compensation Expense and Related Tax Benefits	'
	The following table sets forth share-based compensation expense and related recognized tax benefits.
		Period from			Year Ended December 31,
		January 1, 2014 through June 3,
		2014			2013			2012			2011
	Compensation Expense:
	Stock Options	$	8,248		$	3,426		$	2,621		$	1,497
	Non-vested share awards		11,456			3,918			2,096			1,012
	Deferred Income Tax Benefit		-			2,704			1,726			936

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	1 Months Ended
	Jun. 30, 2014
Commitments and Contingencies [Abstract]	'
Schedule of Future Minimum Commitments Under Operating Lease Obligations	'
	Future minimum commitments as of June 30, 2014 under these operating obligations are as follows (in thousands):
	2015	$	1,199
	2016		1,231
	2017		1,010
	2018		542
	2019		542
	Thereafter		135
	Future minimum commitments	$	4,659

Comparative_Period_Information1

Comparative Period Information (Tables)	1 Months Ended
	Jun. 30, 2014
Comparative Period Information [Abstract]	'
Schedule of Comparative Period Information	'
	The following tables present certain financial information for the six months ended June 30, 2014 and 2013, respectively.  As more fully described in Note 1, “Organization and Summary of Significant Accounting Policies – Basis of Presentation,” due to our new basis of accounting resulting from the Merger, financial information for periods prior to the Merger is not comparable to such information for periods subsequent to the Merger.
		Period from		Period from		Six Months Ended June 30,
		4-Jun-14		1-Jan-14
		through		through
		June 30,		June 3,
		2014		2014		2013 (Unaudited)
		(in thousands)		(in thousands)
	Total revenue	$	60,143	$	276,400	$	366,436
	Income from operations		13,834		23,563		158,244
	Income (loss) before income taxes		10,211		-18,461		155,057
	Deferred income tax expense		-3,574		-4,495		-56,441
	Net income (loss)	$	6,637	$	-22,956	$	98,616
	Basic earnings (loss) per share			$	-0.59	$	2.51
	Diluted earnings (loss) per share			$	-0.59	$	2.48
	Weighted average common shares used in computing
	earnings (loss) per share:
	Basic				38,730		38,847
	Diluted				38,730		39,302
		Period from		Period from		Six Months Ended June 30,
		4-Jun-14		1-Jan-14
		through		through
		June 30,		June 3,
		2014		2014		2013 (Unaudited)
		(in thousands)		(in thousands)
	Net cash provided by operating activities	$	22,209	$	105,122	$	192,476
	Net cash used in investing activities		-200,929		-258,714		-154,969
	Net cash provided by (used in) financing activities		-15,729		344,830		-35,143
	Net increase (decrease) in cash and cash equivalents		-194,449		191,238		2,364
	Cash and cash equivalents at beginning of period		200,050		8,812		1,521
	Cash and cash equivalents at end of period	$	5,601	$	200,050	$	3,885

Interim_Financial_Information_

Interim Financial Information (Tables)	1 Months Ended
	Jun. 30, 2014
Interim Financial Information [Abstract]	'
Schedule of Interim Financial Information (Unaudited)	'
	The following tables summarize our consolidated unaudited interim financial information for the six months ended June 30, 2014 and the year ended December 31, 2013.
			Three		Period from April 1 through			Period from June 4 through
			Months Ended
			March 31 (1)		June 3 (2)			30-Jun
			(In thousands, except per share data)					(In thousands)
	2014
	Revenues		$	159,491	$	116,909			60,143
	Costs and expenses			112,095		140,742			46,309
	Income (loss) from operations			47,396		-23,833			13,834
	Net income (loss)			13,331		-36,287			6,637
	Earnings (loss) per share:
	Basic		$	0.34	$	-0.94
	Diluted			0.34		-0.94
		-1		Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.
		-2		Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.
			Three Months Ended
			31-Mar		30-Jun		September 30(1)			December 31(2)
			(In thousands, except per share data)
	2013
	Revenues		$	182,349	$	184,087	$	183,992		$	142,610
	Costs and expenses			109,657		98,535		143,178			122,077
	Income from operations			72,692		85,552		40,814			20,533
	Net income (loss)			29,037		69,579		-1,284			-12,058
	Earnings (loss) per share:
	Basic		$	0.74	$	1.77	$	-0.03		$	-0.31
	Diluted			0.73		1.75		-0.03			-0.31
	(1)  Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.
	(2)  The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil

Supplementary_Oil_and_Natural_1

Supplementary Oil and Natural Gas Disclosures (Tables)	1 Months Ended
	Jun. 30, 2014
Supplementary Oil and Natural Gas Disclosures [Abstract]	'
Schedule of Estimated Net Proved Reserves, Changes in Estimated Net Proved Reserves and Proved Developed Reserves	'
	The following table sets forth our estimated net proved reserves, changes in our estimated net proved reserves and our net proved developed and undeveloped reserves.
			Oil		Gas		Oil Equivalent
			(Mbbls)		(Mmcf)		(Mboe)
	Estimated Proved Reserves:
	31-Dec-11			27,301		58,785		37,099
	Acquisitions (a)			16,430		115,876		35,742
	Extensions and discoveries (b)			6,388		10,241		8,095
	Revisions			1,128		4,033		1,800
	Production			-3,805		-8,996		-5,304
	31-Dec-12			47,442		179,939		77,432
	Acquisitions			366		209		401
	Sales			-1,415		-916		-1,568
	Extensions and discoveries (c)			7,354		20,247		10,729
	Revisions			3,952		-10,128		2,264
	Production			-6,182		-15,767		-8,810
	31-Dec-13			51,517		173,584		80,448
	Acquisitions (d)			11,640		32,731		17,095
	Extensions and discoveries (e)			418		5,352		1,310
	Revisions (f)			386		-34,791		-5,413
	Production			-3,129		-4,795		-3,928
	30-Jun-14			60,832		172,081		89,512
	Proved developed reserves:
	31-Dec-12			37,908		120,687		58,022
	31-Dec-13			39,439		107,687		57,387
	30-Jun-14			45,232		101,361		62,126
	Proved undeveloped reserves:
	31-Dec-12			9,534		59,252		19,409
	31-Dec-13			12,078		65,897		23,061
	30-Jun-14			15,600		70,720		27,386
	(a)Reserves acquired in the acquisitions of the Hilcorp Properties and the ST41 Interests.
	(b)Includes extensions and discoveries across 6 different fields, primarily within our West Delta and Ship Shoal areas.  These extensions and discoveries added volumes ranging from 18 Mboe to 1.2 Mmboe each, with three exceeding 1.0 Mmboe each.
	(c)Includes extensions and discoveries across 12 different fields, primarily within our Ship Shoal and West Delta areas.  The Ship Shoal 208 field accounts for 46% of our total extensions and discoveries with 4,973 Mboe, consisting of 3,967 Mbbls of oil and 6,035 Mmcf of produced gas.  The remaining 11 locations account for up to 16% each of total extensions and discoveries with reserves ranging from 10 Mboe to 1.6 Mmboe.
	(d)  Reserves acquired in the acquisitions of the EI Interests and the SP49 Interests.
	(e) Includes extensions and discoveries across 3 different fields, primarily within our West Delta, Ship Shoal and Eugene Island areas.  The West Delta field accounts for 68% of our total extensions and discoveries with 890 Mboe, consisting of 50 Mbbls of oil and 5,040 Mmcf of natural gas.  The Ship Shoal 208 field accounts for approximately 23% of our total extensions and discoveries with 295 Mboe, consisting of 260 Mbbls of oil and 212 Mmcf of natural gas.
	(f)  Natural gas revisions also include negative revisions of approximately 35,976 Mmcf related to the exclusion of estimated fuel gas in our natural gas reserves in the June 30, 2014 reserve volumes. This change in methodology reflects fuel gas as negative natural gas reserves rather than a production cost and does not impact future net cash flows after income taxes or standardized measure of discounted future net cash flows. The negative revisions related to this change in the fuel gas methodology were partially offset by increases of approximately 1,185 Mmcf associated with improved performance of certain wells.
Capitalized Costs for Oil and Natural Gas Producing Activities	'
	Capitalized costs for oil and natural gas producing activities consist of the following:
			June 30,
			2014
			(In thousands)
	Proved properties		$	2,316,306
	Unevaluated properties			908,483
	Accumulated depreciation, depletion and amortization			-22,689
	Net capitalized costs		$	3,202,100
			2013
			(In thousands)
	Proved properties		$	2,307,891
	Unproved properties			39,191
	Accumulated depreciation, depletion and amortization			-614,068
	Net capitalized costs		$	1,733,014
Cost Incurred Associated with Finding, Acquiring and Developing Proved Oil and Natural Gas Reserves	'
	The following table sets forth the costs incurred associated with finding, acquiring and developing our proved oil and natural gas reserves.
			Six Months Ended		Year Ended December 31,
			June 30,
			2014		2013		2012		2011
			(In thousands)
	Acquisitions—Proved (1)		$	314,169	$	46,047	$	706,322	$	261,812
	Acquisitions—Unproved			9,503		2,200		7,496		14
	Exploration			56,079		46,100		43,338		17,129
	Development (2)			242,217		303,245		180,938		83,577
	Costs incurred		$	621,968	$	397,592	$	938,094	$	362,532
	(1)For the six months ended June 30, 2014, includes $231 million associated with the acquisition of the SP 49 Interests and $83 million associated with the acquisition of the EI Interests.  See Note 3 “Acquisitions and Dispositions” of the consolidated financial statements in Part II, Item 8 of this Transition Report for further information.
	(2)Includes our estimates during the years ended December 31, 2013, 2012 and 2011 of incurred asset retirement obligations associated with finding and developing our proved oil and natural gas reserves of $1.2 million, $1.2 million and $0.2 million, respectively.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Natural Gas Reserves Disclosure	'
	The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves is as follows:
					December 31,
			June 30,
			2014		2013
			(In thousands)
	Future cash inflows		$	6,704,859	$	5,937,536
	Future production costs			-2,126,110		-1,957,868
	Future development costs (1)			-1,161,289		-1,085,440
	Future income taxes			-712,700		-641,536
	Future net cash flows after income taxes			2,704,760		2,252,692
	10% annual discount for estimated timing of cash flows			-740,167		-603,614
	Standardized measure of discounted future net cash flows		$	1,964,593	$	1,649,078
		-1		Future development cost as of June 30, 2014 include $558.4 million of estimated abandonment and decommissioning costs, net of $120.5 million of estimated salvage values.  Future development costs as of December 31, 2013, include $569.9 million of estimated abandonment and decommissioning costs, net of $25.8 million of estimated salvage values.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Applicable to Proved Oil and Natural Gas Reserves	'
	A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and natural gas reserves for the six months ended June 30, 2014 and the year ended December 31, 2013 is as follows:
			Six Months Ended		Year Ended
			June 30,		December 31,
			2014		2013
			(In thousands)
	Beginning of the period		$	1,649,078	$	1,574,282
	Sales and transfers of oil and natural gas produced, net of production costs			-240,361		-513,906
	Net changes in prices and production costs (1)			-21,599		96,751
	Purchase of minerals in place			471,329		26,708
	Sales of minerals in place			-		-64,539
	Extensions, discoveries and improved recoveries, net of future production costs			49,566		363,493
	Revision of quantity estimates			-325,294		84,490
	Previously estimated development costs incurred during the period			55,888		33,920
	Changes in estimated future development costs			1,560		18,229
	Changes in production rates (timing) and other			170,915		-113,022
	Accretion of discount			210,932		197,927
	Net change in income taxes			-57,421		-55,255
	Net increase			315,515		74,796
	End of period		$	1,964,593	$	1,649,078
	(1)     Our estimated future production costs reflect a decrease related to the previously described change in the fuel gas  methodology to reflect the fuel gas as negative natural gas reserves rather than production cost.
Oil and Natural Gas Computed Price Used in Computation of Discounted Future Net Cash Flows	'
	At June 30, 2014 and December 31, 2013, the computation of the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves was based on the following computed prices:
			2014		2013
	per barrel of oil		$	98.58	$	105.30
	per Mcf for natural gas		$	4.12	$	3.73

Supplemental_Condensed_Consoli1

Supplemental Condensed Consolidating Financial Information (Tables)	1 Months Ended
	Jun. 30, 2014
Supplemental Condensed Consolidating Financial Information [Abstract]	'
Supplemental Condensed Consolidating Balance Sheet	'
	SUCCESSOR COMPANY
	Supplemental Condensed Consolidating Balance Sheet
	As of June 30, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	5,601	$	-	$	-	$	5,601
	Trade accounts receivable - net		72,156		145		-		72,301
	Intercompany receivables		-		26,311		-26,311		-
	Fair value of commodity derivative instruments		-		-		-		-
	Deferred tax asset		24,587		-		-		24,587
	Prepaid expenses		26,521		-		-		26,521
	Total current assets		128,865		26,456		-26,311		129,010
	Net property and equipment		3,034,805		170,382		-		3,205,187
	Investment in affiliates		126,638		-		-126,638		-
	Goodwill		327,235		-		-		327,235
	Restricted cash		6,023		-		-		6,023
	Fair value of commodity derivative instruments		-		-		-		-
	Deferred financing costs		-		-		-		-
	Other assets		226		91		-		317
	Total assets	$	3,623,792	$	196,929	$	-152,949	$	3,667,772
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	90,267	$	656	$	-	$	90,923
	Intercompany payables		26,311		-		-26,311		-
	Accrued expenses		161,503		15		-		161,518
	Asset retirement obligations		33,357		6,474		-		39,831
	Fair value of commodity derivative instruments		26,440		-		-		26,440
	Due to EGC		4,960		-		-		4,960
	Total current liabilities		342,838		7,145		-26,311		323,672
	Long-term debt		1,025,566		-		-		1,025,566
	Asset retirement obligations		193,908		38,956		-		232,864
	Deferred tax liabilities		459,608		24,190		-		483,798
	Fair value of commodity derivative instruments		2,140		-		-		2,140
	Other		6		-		-		6
	Total liabilities		2,024,066		70,291		-26,311		2,068,046
	Stockholders’ equity:
	Preferred stock		-		-		-		-
	Common stock		-		-		-		-
	Additional paid-in capital		1,599,341		85,479		-85,479		1,599,341
	Accumulated other comprehensive income		-6,252		-		-		-6,252
	Treasury stock, at cost		-		-		-		-
	Retained earnings		6,637		41,159		-41,159		6,637
	Total stockholders’ equity		1,599,726		126,638		-126,638		1,599,726
	Total liabilities and stockholders' equity	$	3,623,792	$	196,929	$	-152,949	$	3,667,772
	PREDECESSOR COMPANY
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	8,812	$	-	$	-	$	8,812
	Trade accounts receivable - net		70,520		187		-		70,707
	Intercompany receivables		39,085		-		-39,085		-
	Fair value of commodity derivative instruments		501		-				501
	Deferred tax asset		8,949		-		-		8,949
	Prepaid expenses		6,868		-				6,868
Total current assets		134,735		187		-39,085		95,837
Net property and equipment		1,514,953		221,478		-		1,736,431
Investment in affiliates		122,697		-		-122,697		-
Deposit for Nexen Acquisition		7,040		-		-		7,040
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		238		-		-		238
Deferred financing costs		10,106		-		-		10,106
Other assets		2,067		89		-		2,156
Total assets	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	58,758	$	673	$	-	$	59,431
Intercompany payables		-		39,085		-39,085		-
Accrued expenses		131,111		14		-		131,125
Asset retirement obligations		51,601		-		-		51,601
Fair value of commodity derivative instruments		29,636		-		-		29,636
Total current liabilities		271,106		39,772		-39,085		271,793
Long-term debt		627,355		-		-		627,355
Asset retirement obligations		160,466		43,383		-		203,849
Deferred tax liabilities		106,910		15,902		-		122,812
Fair value of commodity derivative instruments		2,136		-		-		2,136
Other		673		-		-		673
Total liabilities		1,168,646		99,057		-39,085		1,228,618
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		41		-		-		41
Additional paid-in capital		519,114		85,479		-85,479		519,114
Treasury stock		-31,157		-		-		-31,157
Retained earnings		141,215		37,218		-37,218		141,215
Total stockholders’ equity		629,213		122,697		-122,697		629,213
Total liabilities and stockholders' equity	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Balance Sheet
As of December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	1,521	$	-	$	-	$	1,521
Trade accounts receivable - net		66,994		997		-		67,991
Intercompany receivables		55,575		-		-55,575		-
Fair value of commodity derivative instruments		3,302		-				3,302
Deferred tax asset		3,322		-		-		3,322
Prepaid expenses		9,873		-				9,873
Total current assets		140,587		997		-55,575		86,009
Net property and equipment		1,400,768		197,299		-		1,598,067
Investment in affiliates		111,191		-		-111,191		-
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		211		-		-		211
Deferred financing costs		12,386		-		-		12,386
Other assets		2,841		90		-		2,931
Total assets	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	34,740	$	32	$	-	$	34,772
Intercompany payables		-		55,575		-55,575		-
Accrued expenses		117,245		127		-		117,372
Asset retirement obligations		23,982		6,197		-		30,179
Fair value of commodity derivative instruments		10,026		-		-		10,026
Total current liabilities		185,993		61,931		-55,575		192,349
Long-term debt		689,911		-		-		689,911
Asset retirement obligations		187,790		17,141		-		204,931
Deferred tax liabilities		59,571		8,123		-		67,694
Fair value of commodity derivative instruments		3,637		-		-		3,637
Other		1,132						1,132
Total liabilities		1,128,034		87,195		-55,575		1,159,654
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		40		-		-		40
Additional paid-in capital		510,469		85,479		-85,479		510,469
Treasury stock		-20,477		-		-		-20,477
Retained earnings		55,941		25,712		-25,712		55,941
Total stockholders’ equity		545,973		111,191		-111,191		545,973
Total liabilities and stockholders' equity	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
Supplemental Condensed Consolidating Statement of Operations	'
	SUCCESSOR COMPANY
	Supplemental Condensed Consolidating Statement of Operations
	Period from June 4, 2014 through June 30, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Revenue:
	Oil and natural gas	$	53,860	$	5,951	$	-	$	59,811
	Other		114		218		-		332
	Total revenue		53,974		6,169		-		60,143
	Costs and expenses:
	Lease operating		15,282		2,464		-		17,746
	Transportation		299		-		-		299
	Exploration expenditures and dry hole costs		-		-		-		-
	Impairments		-		-		-		-
	Depreciation, depletion and  amortization		20,950		1,825		-		22,775
	Accretion of liability for asset retirement obligations		1,602		420		-		2,022
	General and administrative		2,605		12		-		2,617
	Taxes, other than on earnings		35		815		-		850
	Gain on sale of assets		-		-		-		-
	Other		-		-		-		-
	Total costs and expenses		40,773		5,536		-		46,309
	Income from operations		13,201		633		-		13,834
	Other income (expense):
	Interest income		4		-		-		4
	Interest expense		-3,627		-		-		-3,627
	Loss on derivative instruments		-		-		-		-
	Income from equity investments		412		-		-412		-
	Total other income (expense)		-3,211		-		-412		-3,623
	Income before provision for income taxes		9,990		633		-412		10,211
	Deferred income tax expense		-3,353		-221		-		-3,574
	Net income	$	6,637	$	412	$	-412	$	6,637
	PREDECESSOR COMPANY
	Supplemental Condensed Consolidating Statement of Operations
	Period from January 1, 2014 through June 3, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Revenue:
	Oil and natural gas	$	245,684	$	29,088	$	-	$	274,772
	Other		399		1,229		-		1,628
	Total revenue		246,083		30,317		-		276,400
	Costs and expenses:
	Lease operating		62,116		10,186		-		72,302
	Transportation		1,474		1		-		1,475
	Exploration expenditures and dry hole costs		26,345		-106		-		26,239
	Impairments		61		-		-		61
	Depreciation, depletion and  amortization		76,481		8,646		-		85,127
	Accretion of liability for asset retirement obligations		9,736		2,035		-		11,771
	General and administrative		51,434		-		-		51,434
	Taxes, other than on earnings		377		4,007		-		4,384
	Other		44		-		-		44
	Total costs and expenses		228,068		24,769		-		252,837
	Income from operations		18,015		5,548		-		23,563
	Other income (expense):
	Interest income		17		-		-		17
	Interest expense		-22,621		-		-		-22,621
	Loss on derivative instruments		-19,420		-		-		-19,420
	Income from equity investments		3,529		-		-3,529		-
	Total other income (expense)		-38,495		-		-3,529		-42,024
	Income (loss) before provision for income taxes		-20,480		5,548		-3,529		-18,461
Deferred income tax expense		-2,476		-2,019		-		-4,495
Net income (loss)	$	-22,956	$	3,529	$	-3,529	$	-22,956
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2013
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	606,743	$	82,000	$	-	$	688,743
Other		689		3,606		-		4,295
Total revenue		607,432		85,606		-		693,038
Costs and expenses:
Lease operating		140,605		25,236		-		165,841
Transportation		3,548		20		-		3,568
Exploration expenditures and dry hole costs		22,265		4,290		-		26,555
Impairments		2,937		-		-		2,937
Depreciation, depletion and  amortization		178,427		21,932		-		200,359
Accretion of liability for asset retirement obligations		23,196		5,103		-		28,299
General and administrative		28,137		-		-		28,137
Taxes, other than on earnings		1,084		10,406		-		11,490
Gain on sale of assets		-28,219		-462				-28,681
Other		34,072		870		-		34,942
Total costs and expenses		406,052		67,395		-		473,447
Income from operations		201,380		18,211		-		219,591
Other income (expense):
Interest income		99		-		-		99
Interest expense		-52,368		-		-		-52,368
Gain on derivative instruments		-32,361		-		-		-32,361
Income from equity investments		11,506		-		-11,506		-
Total other income (expense)		-73,124		-		-11,506		-84,630
Income before provision for income taxes		128,256		18,211		-11,506		134,961
Deferred income tax expense		-42,982		-6,705		-		-49,687
Net income	$	85,274	$	11,506	$	-11,506	$	85,274
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	318,749	$	103,780	$	-	$	422,529
Other		15,152		952		-15,000		1,104
Total revenue		333,901		104,732		-15,000		423,633
Costs and expenses:
Lease operating		71,002		23,848		-		94,850
Transportation		611		4		-		615
Exploration expenditures and dry hole costs		18,790		9		-		18,799
Impairments		8,883		-		-		8,883
Depreciation, depletion and  amortization		92,689		20,892		-		113,581
Accretion of liability for asset retirement obligations		10,551		5,014		-		15,565
General and administrative		22,845		15,363		-15,000		23,208
Taxes, other than on earnings		1,162		11,845		-		13,007
Other		5,496		-818		-		4,678
Total costs and expenses		232,029		76,157		-15,000		293,186
Income from operations		101,872		28,575		-		130,447
Other income (expense):
Interest income		136		-		-		136
Interest expense		-28,568		-		-		-28,568
Gain on derivative instruments		-13,305		-		-		-13,305
Income from equity investments		18,945		-		-18,945		-
Total other income (expense)		-22,792		-		-18,945		-41,737
Income before provision for income taxes		79,080		28,575		-18,945		88,710
Deferred income tax expense		-20,270		-9,630		-		-29,900
Net income	$	58,810	$	18,945	$	-18,945	$	58,810
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	245,567	$	102,640	$	-	$	348,207
Other		15,007		113		-15,000		120
Total revenue		260,574		102,753		-15,000		348,327
Costs and expenses:
Lease operating		51,618		18,663		-		70,281
Transportation		766		13		-		779
Exploration expenditures and dry hole costs		14,045		223		-		14,268
Impairments		32,532		-66		-		32,466
Depreciation, depletion and  amortization		82,168		22,456		-		104,624
Accretion of liability for asset retirement obligations		9,013		6,929		-		15,942
General and administrative		18,281		15,460		-15,000		18,741
Taxes, other than on earnings		-733		15,098		-		14,365
Other		9,940		-205		-		9,735
Total costs and expenses		217,630		78,571		-15,000		281,201
Income from operations		42,944		24,182		-		67,126
Other income (expense):
Interest income		102		-		-		102
Interest expense		-17,548		-		-		-17,548
Loss on derivative instruments		-5,870		-		-		-5,870
Loss on early extinguishment of debt		-2,377		-		-		-2,377
Loss from equity investments		15,532		-		-15,532		-
Total other income (expense)		-10,161		-		-15,532		-25,693
Income before provision for income taxes		32,783		24,182		-15,532		41,433
Deferred income tax expense		-6,172		-8,650		-		-14,822
Net income	$	26,611	$	15,532	$	-15,532	$	26,611
Supplemental Condensed Consolidating Statement of Cash Flows	'
	SUCCESSOR COMPANY
	Supplemental Condensed Consolidating Statement of Cash Flows
	Period from June 4, 2014 to June 30, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	22,163	$	46	$	-	$	22,209
	Cash flows provided by (used in) investing activities:
	Property acquisitions		-141,886		-		-		-141,886
	Exploration and development expenditures		-58,930		-46		-		-58,976
	Other property and equipment additions		-67		-		-		-67
	Net cash used in investing activities		-200,883		-46		-		-200,929
	Cash flows provided by (used in) financing activities:
	Proceeds from indebtedness		475,000		-		-		475,000
	Repayments of indebtedness		-475,000		-		-		-475,000
	Advances to EGC		-15,729		-		-		-15,729
	Net cash used in financing activities		-15,729		-		-		-15,729
	Net decrease in cash and cash equivalents		-194,449		-		-		-194,449
	Cash and cash equivalents at beginning of period		200,050		-		-		200,050
	Cash and cash equivalents at end of period	$	5,601	$	-	$	-	$	5,601
	PREDECESSOR COMPANY
	Supplemental Condensed Consolidating Statement of Cash Flows
	Period from January 1, 2014 through June 3, 2014
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	102,307	$	2,815	$	-	$	105,122
	Cash flows provided by (used in) investing activities:
	Property acquisitions		-57,680		-2,815		-		-60,495
	Deposit for Nexen Acquisition		-		-		-		-
	Exploration and development expenditures		-197,968		-		-		-197,968
	Other property and equipment additions		-251		-		-		-251
	Proceeds from sale of assets		-		-		-		-
	Net cash used in investing activities		-255,899		-2,815		-		-258,714
	Cash flows provided by (used in) financing activities:
	Proceeds from indebtedness		345,000		-		-		345,000
	Repayments of indebtedness		-		-		-		-
	Advances to EGC		-						-
	Deferred financing costs		-170		-		-		-170
	Purchase of shares into treasury		-		-		-		-
	Exercise of stock options		-		-		-		-
	Net cash provided by financing activities		344,830		-		-		344,830
	Net increase in cash and cash equivalents		191,238		-		-		191,238
	Cash and cash equivalents at beginning of period		8,812		-		-		8,812
	Cash and cash equivalents at end of period	$	200,050	$	-	$	-	$	200,050
	PREDECESSOR COMPANY
	Supplemental Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	356,597	$	30,962	$	-	$	387,559
	Cash flows provided by (used in) investing activities:
	Property acquisitions		-27,560		-		-		-27,560
	Deposit for Nexen		-7,040		-		-		-7,040
	Exploration and development expenditures		-284,073		-37,967		-		-322,040
	Other property and equipment additions		-2,016		-		-		-2,016
	Proceeds from sale of assets		45,312		7,005		-		52,317
	Net cash used in investing activities		-275,377		-30,962		-		-306,339
	Cash flows provided by (used in) financing activities:
Repayments of indebtedness		-65,000		-		-		-65,000
Deferred financing costs		-674		-		-		-674
Purchase of shares into treasury		-9,640		-		-		-9,640
Exercise of stock options		1,385		-		-		1,385
Net cash used in financing activities		-73,929		-		-		-73,929
Net increase in cash and cash equivalents		7,291		-		-		7,291
Cash and cash equivalents at beginning of period		1,521		-		-		1,521
Cash and cash equivalents at end of period	$	8,812	$	-	$	-	$	8,812
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	190,851	$	23,020	$	-	$	213,871
Cash flows provided by (used in) investing activities:
Property acquisitions		-575,372		-3,000		-		-578,372
Exploration and development expenditures		-165,308		-19,542		-		-184,850
Other property and equipment additions		-1,265		-478		-		-1,743
Net cash used in investing activities		-741,945		-23,020		-		-764,965
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		509,313		-		-		509,313
Repayments of indebtedness		-20,000		-		-		-20,000
Deferred financing costs		-8,469		-		-		-8,469
Purchase of shares into treasury		-8,798		-		-		-8,798
Exercise of stock options		441		-		-		441
Net cash provided by financing activities		472,487		-		-		472,487
Net decrease in cash and cash equivalents		-78,607		-		-		-78,607
Cash and cash equivalents at beginning of period		80,128		-		-		80,128
Cash and cash equivalents at end of period	$	1,521	$	-	$	-	$	1,521
PREDECESSOR COMPANY
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	136,245	$	35,007	$	-	$	171,252
Cash flows provided by (used in) investing activities:
Decrease in restricted cash		2,466		-		-		2,466
Property acquisitions		-235,486		-		-		-235,486
Exploration and development expenditures		-40,996		-35,007		-		-76,003
Other property and equipment additions		-1,568		-		-		-1,568
Net cash used in investing activities		-275,584		-35,007		-		-310,591
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		203,794		-		-		203,794
Deferred financing costs		-6,646		-		-		-6,646
Purchase of shares into treasury		-11,353		-		-		-11,353
Exercise of stock options		119		-		-		119
Net cash provided by financing activities		185,914		-		-		185,914
Net increase in cash and cash equivalents		46,575		-		-		46,575
Cash and cash equivalents at beginning of period		33,553		-		-		33,553
Cash and cash equivalents at end of period	$	80,128	$	-	$	-	$	80,128

Organization_and_Summary_of_Si2

Organization and Summary of Significant Accounting Policies (Narrative) (Details) (USD $)

0 Months Ended

1 Months Ended

2 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

1 Months Ended

Jun. 03, 2014

Jun. 03, 2014

Jun. 30, 2014

31-May-14

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2012

Jan. 15, 2014

Sep. 01, 2013

Sep. 26, 2013

Jan. 01, 2013

Apr. 15, 2012

Apr. 01, 2012

Oct. 31, 2012

Jul. 01, 2012

Jun. 01, 2014

Apr. 02, 2013

Jun. 03, 2014

Jun. 30, 2014

Jun. 30, 2014

Nexen Acquisition [Member]

Nexen Acquisition [Member]

West Delta 29 Acquisition [Member]

West Delta 29 Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

The South Pass 49 [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Energy XXI (Bermuda) Limited [Member]

Minimum [Member]

Maximum [Member]

item

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value

'

'

$0.00

'

$0.00

$0.00

$0.00

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

Aggregate consideration to be paid in acquirer stock

35.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate consideration paid in cash

65.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price

'

'

'

'

'

'

'

'

$64,732,000

$21,800,000

$15,146,000

'

$31,328,000

'

$547,701,000

$230,185,000

'

'

'

'

Acquired certain interests in producing oil and natural gas assets

'

'

'

'

'

'

'

70,400,000

'

'

'

32,400,000

'

'

'

'

'

'

'

'

Number of Leases bid upon

'

'

'

'

'

'

'

5

'

'

'

'

'

'

'

'

'

'

'

'

Gas imbalance asset

'

'

200,000

'

200,000

1,900,000

800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Gas imbalance liability

'

'

2,000,000

'

'

2,000,000

1,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Other property, plant and equipment, useful lives

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'P3Y

'P5Y

Overnight Interest-bearing deposits

'

'

'

'

'

7,300,000

2,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Excess tax benefit from the exercise of stock options

'

0

'

0

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

Allowance for doubtful accounts

'

'

'

'

'

700,000

700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of working interest acquired

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

100.00%

'

'

'

'

'

'

Allowance for doubtful accounts, recoveries

'

'

'

'

'

100,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued exploration costs, development costs and lease operating Costs

'

'

127,600,000

'

127,600,000

107,800,000

84,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Other accrued expenses

'

'

18,100,000

'

18,100,000

7,500,000

16,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Sale of non-operated Bay Marchand field

'

'

'

'

'

'

'

'

'

$16,500,000

'

'

'

'

'

'

$62,800,000

'

'

'

Pushdown_Accounting_Narrative_

Pushdown Accounting (Narrative) (Details)	1 Months Ended	5 Months Ended	12 Months Ended
	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pushdown Accounting [Abstract]	'	'	'	'	'
Tax rate used to recognize deferred income taxes	37.00%	'	'	'	'
Statutory federal income tax rate	35.00%	35.00%	35.00%	35.00%	35.00%
Statutory state tax rate, net of federal tax rate	2.00%	'	'	'	'

Pushdown_Accounting_Schedule_o

Pushdown Accounting (Schedule of Pushdown Accounting Adjustments on Balance Sheets) (Details) (USD $)

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2012

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Jun. 03, 2014

Jun. 30, 2014

Jun. 03, 2014

In Thousands, unless otherwise specified

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Pushdown Adjustment [Member]

Successor Company [Member]

Successor Company [Member]

Current assets:

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

$5,601

$200,050

$8,812

$3,885

$1,521

$200,050

$8,812

$1,521

$80,128

$33,553

'

$5,601

$200,050

Trade accounts receivable - net

'

'

'

'

'

91,813

70,707

67,991

'

'

1,194

72,301

93,007

Deferred tax asset

24,587

'

8,949

'

3,322

8,405

8,949

3,322

'

'

16,182

24,587

24,587

Prepaid expenses

'

'

'

'

'

9,729

6,868

9,873

'

'

80

26,521

9,809

Total current assets

'

'

'

'

'

309,997

95,837

86,009

'

'

17,456

129,010

327,453

Property and equipment, net of accumulated depreciation, depletion and amortization

3,205,187

'

1,736,431

'

1,598,067

1,969,382

1,736,431

1,598,067

'

'

972,510

3,205,187

2,941,892

Goodwill

'

'

'

'

'

'

'

'

'

'

327,235

327,235

327,235

Restricted cash

'

'

'

'

'

6,023

6,023

6,023

'

'

'

6,023

6,023

Fair value of commodity derivative instruments

'

'

238

'

211

27

238

211

'

'

'

'

27

Deferred financing costs

'

'

'

'

'

9,002

10,106

12,386

'

'

-9,002

'

'

Other assets

'

'

'

'

'

1,175

2,156

2,931

'

'

'

317

1,175

Total Assets

'

'

'

'

'

2,295,606

1,857,831

1,705,627

'

'

1,308,199

3,667,772

3,603,805

Current liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts payable

'

'

'

'

'

61,938

59,431

34,772

'

'

'

90,923

61,938

Accrued expenses

'

'

'

'

'

230,086

131,125

117,372

'

'

'

161,518

230,086

Asset retirement obligations

39,831

39,859

51,601

'

30,179

39,859

51,601

30,179

'

'

3,758

39,831

43,617

Fair value of commodity derivative instruments

26,440

'

29,636

'

10,026

22,625

29,636

10,026

'

'

'

26,440

22,625

Total current liabilities

'

'

'

'

'

354,508

271,793

192,349

'

'

3,758

323,672

358,266

Long-term debt

1,025,566

'

627,355

'

689,911

973,440

627,355

689,911

'

'

52,967

1,025,566

1,026,407

Asset retirement obligations

232,864

220,302

203,849

'

204,931

220,302

203,849

204,931

'

'

9,453

232,864

229,755

Deferred tax liabilities

483,798

'

122,812

'

67,694

126,764

122,812

67,694

'

'

356,827

483,798

483,591

Fair value of commodity derivative instruments

2,140

'

2,136

'

3,637

1,439

2,136

3,637

'

'

'

2,140

1,439

Other

'

'

'

'

'

803

673

1,132

'

'

-797

6

6

Total Liabilities

'

'

'

'

'

1,677,256

1,228,618

1,159,654

'

'

422,208

2,068,046

2,099,464

Commitments and contingencies

'

'

'

'

'

'

'

'

'

'

'

'

'

Stockholders' equity:

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, par value $0.001 per share

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value $0.001 per share

'

'

'

'

'

41

41

40

'

'

-41

'

'

Additional paid-in capital

'

'

'

'

'

538,844

519,114

510,469

'

'

965,497

1,599,341

1,504,341

Treasury stock, at cost

'

'

'

'

'

-38,794

-31,157

-20,477

'

'

38,794

'

'

Retained earnings

'

'

'

'

'

118,259

141,215

55,941

'

'

-118,259

6,637

'

Total stockholders' equity

'

'

'

'

'

618,350

629,213

545,973

491,045

473,116

885,991

1,599,726

1,504,341

Total liabilities and stockholders' equity

'

'

'

'

'

$2,295,606

$1,857,831

$1,705,627

'

'

$1,308,199

$3,667,772

$3,603,805

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions (Narrative) (Details) (USD $)

1 Months Ended

5 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

5 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

5 Months Ended

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2014

Jun. 03, 2014

Jun. 30, 2014

Jun. 01, 2014

31-May-14

Jun. 03, 2014

Sep. 26, 2013

Dec. 31, 2013

Jan. 01, 2013

Oct. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Jul. 01, 2012

Oct. 31, 2012

Oct. 25, 2012

15-May-12

Apr. 15, 2012

Dec. 31, 2012

Apr. 01, 2012

Apr. 02, 2013

Apr. 02, 2013

Dec. 31, 2013

Jan. 15, 2014

Jun. 03, 2014

Sep. 01, 2013

Jan. 17, 2014

Nov. 26, 2013

Oct. 31, 2012

1-May-12

8.25% Senior Notes [Member]

The South Pass 49 [Member]

The South Pass 49 [Member]

The South Pass 49 [Member]

The South Pass 49 [Member]

The South Pass 49 [Member]

West Delta 29 Acquisition [Member]

West Delta 29 Acquisition [Member]

West Delta 29 Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Nexen Acquisition [Member]

Nexen Acquisition [Member]

Nexen Acquisition [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

MMBoe

Parent Company [Member]

Energy XXI (Bermuda) Limited [Member]

MMBoe

MMBoe

MMBoe

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

MMBoe

MMBoe

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Date of acquisition

'

'

'

'

'

3-Jun-14

'

'

'

'

26-Sep-13

'

'

31-Oct-12

'

'

'

'

'

'

15-May-12

'

'

'

2-Apr-13

'

'

15-Jan-14

'

'

'

'

'

'

Acquired certain interests in producing oil and natural gas assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$32,400,000

'

'

'

'

'

$70,400,000

'

'

'

'

'

'

Purchase price

'

'

'

'

'

'

'

230,185,000

'

'

21,800,000

'

15,146,000

'

'

'

'

547,701,000

'

'

'

'

'

31,328,000

'

'

'

'

'

64,732,000

'

'

'

'

Percentage of oil reserves

'

'

'

'

'

74.00%

'

'

'

'

'

95.00%

'

'

49.00%

49.00%

'

'

'

'

51.00%

'

'

'

'

'

'

91.00%

'

'

'

'

'

'

Percentage of proved developed reserves

'

'

'

'

'

73.00%

'

'

'

'

'

58.00%

'

'

58.00%

58.00%

'

'

'

'

84.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of ownership interest

100.00%

'

'

'

'

100.00%

'

'

43.50%

56.50%

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

Proved reserves BOE

'

'

'

'

'

11.3

'

'

'

'

'

0.7

'

'

37.2

37.2

'

'

'

'

1

'

'

'

'

'

'

2.6

'

'

'

'

'

'

Economic effective date

'

'

'

'

'

1-Jun-14

'

'

'

'

'

1-Jan-13

'

'

'

1-Jul-12

'

'

'

'

1-Apr-12

'

'

'

'

'

1-Jan-13

1-Sep-13

'

'

'

'

'

'

Purchase price adjustments

'

'

'

'

'

200,000

'

'

'

'

'

7,100,000

'

'

5,700,000

5,700,000

'

'

'

'

400,000

'

'

'

'

'

700,000

5,700,000

'

'

'

'

'

'

Revisions

'

7,415,000

24,586,000

22,308,000

'

'

'

'

'

'

'

'

'

'

'

'

22,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incurred fees

'

'

'

'

'

'

300,000

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

'

100,000

'

'

'

'

'

100,000

'

'

'

'

'

Increase in line of credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

Cash consideration from sale of proptery

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51,500,000

'

'

'

'

'

'

'

'

'

Buyer's assumption of liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,300,000

11,300,000

'

'

'

'

'

'

'

'

Working interest by acquiree prior to acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

'

'

'

'

'

'

'

Working interest by acquirer prior to acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60.00%

'

'

'

'

'

'

'

'

'

'

Sale of non-operated Bay Marchand field

'

'

'

'

'

'

'

'

'

'

16,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

62,800,000

62,800,000

'

'

'

'

'

'

'

'

Gain (Loss) on Sale of Properties, before Applicable Income Taxes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,100,000

'

'

'

'

'

'

'

'

Borrowings under line of credit

'

'

'

'

'

135,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capital contribution from EGC

'

'

'

'

'

95,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base under the expanded credit facility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

475,000,000

425,000,000

425,000,000

200,000,000

Senior notes, face amount

'

'

'

'

$510,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

$300,000,000

$300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes, stated percentage

'

'

'

'

8.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions (Schedule of Carry Amount of Net Assets Sold) (Details) (USD $)	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jan. 01, 2013
In Thousands, unless otherwise specified						Non-Operated Bay Marchand Field Disposition [Member]
Business Acquisition [Line Items]	'	'	'	'	'	'
Net property and equipment	'	'	'	'	'	$35,298
Asset retirement obligations	-272,695	-260,161	-255,450	-235,110	-99,347	-3,959
Other liabilities	'	'	'	'	'	-7,311
Net assets sold	'	'	'	'	'	$24,028

Acquisitions_and_Dispositions_3

Acquisitions and Dispositions (Schedule of Assets Acquired and Liabilities Assumed) (Details) (USD $)

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 01, 2014

Jul. 01, 2012

Apr. 01, 2012

Sep. 01, 2013

Sep. 26, 2013

Jan. 01, 2013

Jan. 01, 2013

In Thousands, unless otherwise specified

The South Pass 49 [Member]

Hilcorp Acquisition [Member]

South Timbalier Acquisition [Member]

Nexen Acquisition [Member]

West Delta 29 Acquisition [Member]

West Delta 29 Acquisition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Acquired Indefinite-lived Intangible Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas properties

'

'

'

'

'

$231,271

$698,660

$33,206

$82,897

'

$16,544

'

Asset retirement obligations

-272,695

-260,161

-255,450

-235,110

-99,347

-1,086

-150,959

-1,878

-18,165

'

-1,398

-3,959

Net assets acquired

'

'

'

'

'

$230,185

$547,701

$31,328

$64,732

$21,800

$15,146

'

Acquisitions_and_Dispositions_4

Acquisitions and Dispositions (Schedule of Revenues and Leases Operating Expenses Attributable to Acquired Oil and Gas Properties) (Details) (USD $)	1 Months Ended	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012
The South Pass 49 [Member]	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	$5,126	'	'	'
Lease operating expenses	600	'	'	'
Hilcorp Properties Acquisition [Member]	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	22,455	100,571	208,241	37,978
Lease operating expenses	7,489	29,189	74,404	10,982
South Timbalier Acquisition [Member]	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	843	3,406	11,189	9,262
Lease operating expenses	148	1,217	2,468	1,760
West Delta 29 Acquisition [Member]	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	1,232	5,681	3,011	'
Lease operating expenses	12	89	44	'
Nexen Acquisition [Member]	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'
Revenues	4,379	17,565	'	'
Lease operating expenses	$1,151	$7,264	'	'

Acquisitions_and_Dispositions_5

Acquisitions and Dispositions (Schedule of Consolidated Results of Operations) (Details) (USD $)	5 Months Ended	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 03, 2014	Dec. 31, 2013
Acquisitions and Dispositions [Abstract]	'	'
Revenue	$303,742	$823,436
Net income (loss)	($15,546)	$122,391
Basic earnings per share	($0.40)	$3.13
Diluted earnings per share	($0.40)	$3.09

Common_Stock_Narrative_Details

Common Stock (Narrative) (Details) (USD $)	1 Months Ended			12 Months Ended				0 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 31, 2013	31-May-12	Aug. 31, 2011	Dec. 31, 2013	Jun. 30, 2014	Apr. 30, 2013	26-May-11	Jun. 03, 2014	Jun. 03, 2014	Jun. 03, 2014
					2009 Long Term Incentive Plan [Member]	2009 Long Term Incentive Plan [Member]	2009 Long Term Incentive Plan [Member]	Successor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]
								Stock Election [Member]	Mixed Election [Member]	Equity Option [Member]
Business acquisition, per share price of acquiree's share	'	'	'	'	'	'	'	'	'	$39
Share conversion ratio	'	'	'	'	'	'	'	1.669	0.584	'
Business Acquisition, per share price of acquiror share	'	'	'	'	'	'	'	'	$25.35	'
Stock repurchase program, amount authorized	$80	$40	$20	'	'	'	'	'	'	'
Stock repurchase program, share repurchased amount	'	'	'	$29.70	'	'	'	'	'	'
Number of shares repurchased	'	'	'	1,799,000	'	'	'	'	'	'
Reserved shares of common stock for issuance	'	'	'	'	'	3,574,000	2,474,000	'	'	'
Remaining shares for issuance	'	'	'	'	1,087,347	'	'	'	'	'

Earnings_per_Share_Basic_and_D

Earnings per Share (Basic and Diluted Weighted Average Shares Outstanding and Earnings per Share) (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

5 Months Ended

6 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Jun. 30, 2014

Jun. 03, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 03, 2014

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Earnings per Share [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

$6,637

($36,287)

[1]

$13,331

[2]

($12,058)

[3]

($1,284)

[4]

$69,579

$29,037

($22,956)

$98,616

$85,274

$58,810

$26,611

Net income attributable to participating securities

'

'

'

'

'

'

'

'

'

-943

-455

-77

Net income attributed to common shares

'

'

'

'

'

'

'

($22,956)

'

$84,331

$58,355

$26,534

Weighted average shares - basic

'

'

'

'

'

'

'

38,730

38,847

38,730

38,885

39,946

Dilutive effect of stock options

'

'

'

'

'

'

'

'

'

506

149

104

Weighted average shares - diluted

'

'

'

'

'

'

'

38,730

39,302

39,236

39,034

40,050

Basic earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.77

$0.74

($0.59)

$2.51

$2.18

$1.50

$0.66

Diluted earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.75

$0.73

($0.59)

$2.48

$2.15

$1.50

$0.66

[1]

Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.

[2]

Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.

[3]

The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.

[4]

Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.

Earnings_per_Share_Number_of_A

Earnings per Share (Number of Antidilutive Shares Excluded from the Computation of Dilutive Weighted Average Shares) (Details)	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings per Share [Abstract]	'	'	'	'
Weighted average shares	941	273	687	442

Property_and_Equipment_Schedul

Property and Equipment (Schedule of Property and Equipment) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property and Equipment [Abstract]	'	'	'
Proved oil and natural gas properties	$2,316,306	$2,307,891	$1,982,657
Unevaluated oil and natural gas properties	908,483	39,191	36,992
Other	3,173	8,137	5,998
Less: accumulated depreciation, depletion and amortization	-22,775	-618,788	-427,580
Net property and equipment	$3,205,187	$1,736,431	$1,598,067

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Narrative) (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'	'
Increase in asset retirement obligations due to revisions	'	$20.80
Loss on abandonment activities of non operated interests	$22.60	$20.80

Asset_Retirement_Obligations_S

Asset Retirement Obligations (Schedule of Changes in Asset Retirement Obligations) (Details) (USD $)	1 Months Ended	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligations [Abstract]	'	'	'	'
Beginning of period total	$260,161	$255,450	$235,110	$99,347
Accretion expense	2,022	11,771	28,299	15,565
Liabilities assumed in acquisition	1,086	18,165	23,541	132,109
Pushdown accounting fair value adjustment	13,213	'	'	'
Liabilities incurred	'	'	1,187	1,210
Revisions	'	7,415	24,586	22,308
Liabilities associated with assets sold	'	'	-3,965	'
Liabilities settled	-3,787	-32,640	-53,308	-35,429
End of period total	272,695	260,161	255,450	235,110
Less: End of period, current portion	-39,831	-39,859	-51,601	-30,179
End of period, noncurrent portion	$232,864	$220,302	$203,849	$204,931

Indebtedness_Narrative_Details

Indebtedness (Narrative) (Details) (USD $)

1 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

1 Months Ended

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Oct. 31, 2012

Jun. 30, 2014

31-May-14

Jan. 17, 2014

Dec. 31, 2013

Nov. 26, 2013

1-May-12

Feb. 14, 2011

Jun. 30, 2014

Jun. 30, 2014

Mar. 31, 2015

Jun. 30, 2015

Jun. 30, 2014

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 03, 2014

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Apr. 18, 2014

Feb. 14, 2011

Jul. 01, 2012

Oct. 25, 2012

Oct. 31, 2012

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Energy XXI Gulf Coast Inc [Member]

Eighth Amendment as of June 3, 2014 [Member]

Eighth Amendment as of June 3, 2014 [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

Maximum [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

ASOP Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Base Rate plus margin [Member]

Base Rate plus margin [Member]

LIBOR plus margin [Member]

LIBOR plus margin [Member]

LIBOR plus margin [Member]

LIBOR plus margin [Member]

Federal Funds Rate [Member]

Federal Funds Rate [Member]

Energy XXI Gulf Coast Inc [Member]

Eighth Amendment as of June 3, 2014 [Member]

Revolving Credit Sub-facility [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Revolving Credit Sub-facility [Member]

Minimum [Member]

Maximum [Member]

Parent Company [Member]

2011 Senior Notes [Member]

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Minimum [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Energy XXI Gulf Coast Inc [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Revolving Credit Sub-facility [Member]

Revolving Credit Sub-facility [Member]

Eighth Amendment as of June 3, 2014 [Member]

Revolving Credit Sub-facility [Member]

Eighth Amendment as of June 3, 2014 [Member]

Revolving Credit Sub-facility [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Energy XXI Gulf Coast Inc [Member]

Market Rate Applies [Member]

Market Rate Applies [Member]

Market Rate Applies [Member]

Market Rate Applies [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes, face amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$510,000,000

'

'

'

'

'

'

$210,000,000

'

$300,000,000

$300,000,000

'

'

'

'

'

'

'

'

Carrying Value

1,025,566,000

627,355,000

689,911,000

'

'

'

'

475,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

550,566,000

497,355,000

'

494,911,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes, stated percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,700,000

547,701,000

'

'

'

'

'

'

'

'

'

'

Maturity date

'

'

'

'

'

'

31-Oct-16

'

'

'

'

'

'

'

9-Apr-18

'

'

'

'

'

'

'

'

'

15-Feb-18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from offering of Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

202,000,000

'

289,500,000

'

'

'

'

'

'

'

'

'

Senior secured credit facility

'

'

'

'

'

475,000,000

750,000,000

'

'

'

750,000,000

'

'

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base under the expanded credit facility

'

'

'

'

'

1,500,000,000

425,000,000

'

'

475,000,000

'

425,000,000

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in line of credit facility

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.75%

1.75%

1.75%

1.75%

2.75%

2.75%

0.75%

1.75%

Aggregate principal amount for which valid consents were received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

484,100,000

'

'

'

'

'

'

'

'

'

'

'

'

Cash payment per $1,000 principal amount for which consents were delivered

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

Amounts drawn under Senior Credit Facility

'

'

'

475,000,000

'

'

'

'

475,000,000

'

130,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt redemption notice

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'60 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowings outstanding

'

'

'

'

475,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum debt owned for repurchase right

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum debt owned for repurchase right, additional increments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase right, redemption percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase period after sale of assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'360 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum proceeds from sale of assets that must be applied to senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase Percentage of Senior Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum amount of letters of credit that is outstanding

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total leverage of EGC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.25%

4.00%

3.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Secured debt not to exceed EBITDA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

1.75%

1.75%

1.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effective interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5.80%

'

9.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest included in purchase price

$15,800,000

$15,800,000

$16,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,800,000

'

'

'

'

'

'

'

'

'

Percentage of debt used for debt exchange

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Indebtedness_Schedule_of_Indeb

Indebtedness (Schedule of Indebtedness) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012	Oct. 31, 2012	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2014
In Thousands, unless otherwise specified				8.25% Senior Notes [Member]	8.25% Senior Notes [Member]	8.25% Senior Notes [Member]	Revolving Credit Sub-facility [Member]	Revolving Credit Sub-facility [Member]	Revolving Credit Sub-facility [Member]	Revolving Credit Sub-facility [Member]	Revolving Credit Sub Facility [Member]
Total indebtedness	$1,025,566	$627,355	$689,911	$550,566	$497,355	$494,911	'	'	$130,000	$195,000	$475,000
Current portion of indebtedness	'	'	'	'	'	'	'	'	'	'	'
Noncurrent portion of indebtedness	$1,025,566	$627,355	$689,911	$550,566	$497,355	$494,911	'	$475,000	'	'	'
Senior notes, stated percentage	'	'	'	8.25%	'	'	'	'	'	'	'
Maturity date	'	'	'	15-Feb-18	'	'	31-Oct-16	'	'	'	'

Indebtedness_Schedule_of_Redee

Indebtedness (Schedule of Redeemable Debt) (Details)	1 Months Ended
	Jun. 30, 2014
Indebtedness [Abstract]	'
2015	104.13%
2016	102.06%
2017 and thereafter	100.00%

Concentrations_Narrative_Detai

Concentrations (Narrative) (Details)	1 Months Ended	5 Months Ended	12 Months Ended
	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012
Customer 1 Concentration Risk [Member]	'	'	'	'
Percentage of total oil and natural gas revenues	55.00%	52.00%	63.00%	45.00%
Customer 2 Concentration Risk [Member]	'	'	'	'
Percentage of total oil and natural gas revenues	23.00%	23.00%	24.00%	31.00%
Customer 3 Concentration Risk [Member]	'	'	'	'
Percentage of total oil and natural gas revenues	11.00%	10.00%	6.00%	11.00%

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Narrative) (Details) (USD $)	1 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Derivative Instruments and Hedging Activities [Abstract]	'
Loss reclassified from AOCI	($1.60)
Amount expected to be reclassified from other comprehensive income to income, gross	8.8
Amount expected to be reclassified from other comprehensive income to income, net	$5.70

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Schedule of Derivative Instruments Outstanding) (Details)	Jun. 30, 2014
	bbl
July 2014 - December 2014 [Member] | Oil Contract [Member] | Fixed Price Swaps [Member]	'
Derivative [Line Items]	'
Daily Average Volume	8,769
Volume, Oil Contracts	1,613,550
Average Swap Price	92.84
July 2014 - December 2014 [Member] | Gas Contract [Member] | Fixed Price Swaps [Member]	'
Derivative [Line Items]	'
Volume, Gas Contracts	920,000
Average Swap Price	4.01
July 2014 - December 2014 [Member] | Gas Contract [Member] | Three-Way Collars [Member]	'
Derivative [Line Items]	'
Volume, Gas Contracts	1,257,000
Sub Floor	3.25
Floor	4
Ceiling	4.76
July 2014 - December 2014 [Member] | Gas Contract [Member] | Put Spreads [Member]	'
Derivative [Line Items]	'
Volume, Gas Contracts	583,000
Sub Floor	3.25
Floor	4
January 2015 - December 2015 [Member] | Oil Contract [Member] | Fixed Price Swaps [Member]	'
Derivative [Line Items]	'
Daily Average Volume	1,500
Volume, Oil Contracts	547,500
Average Swap Price	97.7
January 2015 - December 2015 [Member] | Gas Contract [Member] | Fixed Price Swaps [Member]	'
Derivative [Line Items]	'
Volume, Gas Contracts	1,569,500
Average Swap Price	4.31

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Components of Gain (Loss) on Derivative Instruments) (Details) (USD $)	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments and Hedging Activities [Abstract]	'	'	'	'
Change in fair market value	$6,996	($20,884)	($9,491)	$11,475
Loss on settlement	-26,416	-11,477	-3,814	-17,345
Total loss on derivative instruments	($19,420)	($32,361)	($13,305)	($5,870)

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Debt Instruments) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'	'	'
Carrying Value	$1,025,566	$627,355	$689,911
Estimated Fair Value	1,020,700	676,338	719,600
8.25% Senior Notes [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Senior notes, stated percentage	8.25%	'	'
Carrying Value	550,566	497,355	494,911
Estimated Fair Value	545,700	546,338	524,600
Revolving Credit Sub-facility [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Carrying Value	475,000	'	'
Estimated Fair Value	475,000	'	'
Prior Senior Credit Facility [Member]	'	'	'
Debt Instrument [Line Items]	'	'	'
Carrying Value	'	130,000	195,000
Estimated Fair Value	'	$130,000	$195,000

Fair_Value_Measurements_Schedu1

Fair Value Measurements (Schedule of Fair Value Measurements of Assets and Liabilities) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Measurements [Abstract]	'	'	'
Current	'	$501	$3,302
Noncurrent	'	238	211
Total gross fair value	'	739	3,513
Less: counterparty set-off	'	-739	-3,513
Total net fair value	'	'	'
Current	26,440	29,636	10,026
Noncurrent	2,140	2,136	3,637
Total gross fair value	28,580	31,772	13,663
Less: counterparty set-off	'	-739	-3,513
Total net fair value	$28,580	$31,033	$10,150

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	1 Months Ended
	Jun. 30, 2014	Sep. 25, 2009
Percentage of ownership interest	100.00%	'
Reduction in net operating loss carryforward	'	$97,000,000
Operating loss carryforwards	191,000,000	'
Net operating loss carryforward, share-based compensation	28,800,000	'
Unused annual limited net operating loss carryforward	'	137,000,000
Annual limitation net operating loss carryforward	21,000,000	'
Net operating loss carryforward available current year	130,000,000	'
Uncertain tax positions	'no	'
Cash credit carryforward	$36,000	'

Income_Taxes_Schedule_of_Incom

Income Taxes (Schedule of Income Tax Benefit (Expense) (Details) (USD $)	1 Months Ended	5 Months Ended	6 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Jun. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred:	'	'	'	'	'	'
Federal	($3,574)	($4,318)	'	($47,723)	($28,719)	($14,468)
State	'	-177	'	-1,964	-1,181	-354
Total deferred	-3,574	-4,495	'	-49,687	-29,900	-14,822
Total, Federal	-3,574	-4,318	'	-47,723	-28,719	-14,468
Total, State	'	-177	'	-1,964	-1,181	-354
Total provision for income taxes	($3,574)	($4,495)	($56,441)	($49,687)	($29,900)	($14,822)

Income_Taxes_Reconciliation_of

Income Taxes (Reconciliation of Effective Income Tax Rate (Benefit)) (Details)	1 Months Ended	5 Months Ended	12 Months Ended
	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Taxes [Abstract]	'	'	'	'	'
Statutory federal income tax rate	35.00%	35.00%	35.00%	35.00%	35.00%
State taxes	'	1.40%	1.40%	1.40%	2.30%
Non-deductible items	'	-59.50%	'	'	'
Change in state tax rate	'	'	'	-2.70%	-1.70%
Statutory depletion	'	'	-0.30%	-0.40%	-1.00%
Other	'	-1.20%	0.70%	0.40%	1.20%
Effective income tax rate (benefit)	35.00%	-24.30%	36.80%	33.70%	35.80%

Income_Taxes_Schedule_of_Tax_E

Income Taxes (Schedule of Tax Effect of Temporary Differences) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Income Taxes [Abstract]	'	'	'
Federal and state net operating loss carryforwards	$61,546	$62,015	$62,130
Fair value of commodity derivative instruments	12,136	11,578	3,912
Restricted stock awards and options	'	3,843	2,313
Percentage depletion carryforward	'	5,003	4,575
Basis differences in indebtedness	19,651	'	'
Accruals and other	701	1,130	2,613
Deferred tax asset	94,034	83,569	75,543
Property, plant and equipment, principally due to differences in depreciation	550,435	193,191	136,016
Fair value of commodity derivative instruments	'	182	214
Prepaid assets	1,663	1,482	1,778
Accruals and other	1,147	2,577	1,907
Deferred tax liabilities	553,245	197,432	139,915
Total deferred tax Liabilities	459,211	113,863	64,372
Current deferred asset	24,587	8,949	3,322
Deferred tax liabilities	483,798	122,812	67,694
Total net deferred tax liability	$459,211	$113,863	$64,372

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)

5 Months Ended

6 Months Ended

12 Months Ended

5 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

5 Months Ended

12 Months Ended

5 Months Ended

1 Months Ended

12 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

1 Months Ended

5 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

Jun. 03, 2014

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2009

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Apr. 30, 2013

26-May-11

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jun. 03, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Feb. 28, 2014

Jan. 31, 2014

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2014

Sep. 30, 2009

Jun. 30, 2014

Dec. 31, 2012

Jun. 03, 2014

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Restricted Stock [Member]

Maximum [Member]

Minimum [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

401(K) Plans [Member]

401(K) Plans [Member]

2006 Long Term Incentive Plan [Member]

2006 Long Term Incentive Plan [Member]

2006 Long Term Incentive Plan [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Predecessor Company [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Restricted Stock [Member]

Parent Company [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

Equity Option [Member]

Parent Company [Member]

Parent Company [Member]

Restricted Stock [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee retention, possible percentage of salary and bonuses

'

'

'

'

'

'

'

'

'

'

'

299.00%

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Salary, bonuses and other benefit expenses due to change of control

$11,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued bonuses, current

5,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted Stock, Granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

161,370

'

'

349,481

'

'

'

'

'

12,984

15,305

31,095

'

68,116

'

'

'

Allocated Share-based Compensation Expense

'

'

'

'

'

'

8,248,000

3,426,000

2,621,000

1,497,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

'

'

'

'

'

'

'

'

'

'

100,000

'

Modification of September 30, 2009 employment agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'On May 1, 2012, the former Compensation Committee modified the terms of the Option Agreement to extend the expiration of the stock options granted thereunder to September 30, 2019, resulting in additional compensation expense of $0.1 million in the year ended December 31, 2012. Upon a change in control as defined in the 2009 LTIP, all stock options under the Option Agreement remain exercisable for a period of not less than 30 months following the change in control. Prior to February 2014, the former Compensation Committee approved a compensation program for each of our former non-employee directors which provided for the annual grant of a stock award with a market value of $100,000 (as measured on the date of the grant and prorated from the date of the grant, if applicable). In February 2014, the former Compensation Committee approved an increase in the annual grant of a stock award from a market value of $100,000 to a market value of $125,000 (as measured on the date of the grant and prorated from the date of the grant, if applicable) for each of our former non-employee directors. Pursuant to the terms of the program,

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,574,000

2,474,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant

'

'

'

'

'

'

'

'

'

'

'

'

'

1,087,347

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'term of 10 years and vested ratably on an annual basis over a three-year period from the date of grant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'one-half of each stock award vested immediately on the date of grant, and the remaining one-half vested immediately prior to the next annual meeting of stockholders held after the grant date.

'P3Y

'The terms of the Option Agreement provided for an exercise price equal to $10.00 per share. The closing price of our common stock on the NYSE on SeptemberB 30, 2009 was $7.46 per share. The option vested ratably on a monthly basis over a 36-month period from the date of grant; however, the vesting for the first six months of the vesting period (the "Initial Period") was deferred until the end of the Initial Period and any remaining unvested portion vested ratably on a monthly basis over the remainder of the 36-month vesting period, subject to the executive remaining continuously employed. Under the original terms of the award agreement, vested stock options under the Option Agreement were to expire 30 months following the applicable vesting date of such stock options.

'

'

Award term

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

Weighted-average grant-date fair value of stock options granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$14.57

$14.50

$8.84

$7.97

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-average grant-date fair value nonvested share awards granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$25.08

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate instrinsic value of stock options exercised during period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

32,600,000

2,100,000

500,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of stock issued, non-employee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

125,000

100,000

'

'

'

'

'

'

'

'

'

Deferred Compensation Arrangement with Individual, Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'Pursuant to elections made by two directors applicable to certain of these awards, the receipt of such awards totaling 39,009 shares was deferred until such directors ceased to serve on our Board of Directors. In conjunction with the Merger, each option to purchase shares of Common Stock outstanding immediately prior to the effective date of the Merger under the 2009 LTIP, whether or not then exercisable or vested, was deemed exercised pursuant to a cashless exercise for that number of shares of Common Stock (the "net exercise shares") equal to (i) the number of shares of Common Stock subject to such stock option immediately prior to the effective date minus (ii) the number of whole and partial shares of Common Stock subject to such stock option that, when multiplied by $39.00 per share, was equal to the aggregate exercise price of such stock option. Each net exercise share deemed to be an outstanding share of Common Stock received merger consideration of $39.00 in cash and was not subject to proration like other holders of Common Stock that elected to receive all cash in the Merger.

'

'

'

'

Deferred Compensation Arrangement with Individual, Shares Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

39,009

'

'

'

'

'

'

'

'

Description of 401(K) Plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'We also have a 401(k) Plan that covers all employees. We match 100% of each individual participant's contribution not to exceed 6% of the participant's compensation. Our matching contributions are made in cash.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Employer Discretionary Contribution Amount

'

$300,000

$900,000

$800,000

$700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$26.79

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$10

'

'

'

Share price

'

'

'

'

'

$7.46

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business acquisition, per share price of acquiree's share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$39

Shares issued, accerlerated

'

'

'

'

'

'

'

'

'

'

471,080

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Employee_Benefit_Plans_Stock_O

Employee Benefit Plans (Stock Option Activity) (Details) (Employee Stock Option [Member], USD $)	5 Months Ended
	Jun. 03, 2014
Weighted Average Remaining Contractual Terms, Outstanding on June 3, 2014	'0 years
Weighted Average Remaining Contractual Terms, Exercisable on June 3, 2014	'0 years
Aggregate Intrinsic Value, Outstanding on June 3, 2014	'
Aggregate Intrinsic Value, Exercisable on June 3, 2014	'
2009 Long Term Incentive Plan [Member]	'
Options, Outstanding on December 31, 2013	1,453,173
Options, Granted	143,114
Options, Exercised	-1,596,287
Weighted Average Exercise Price per Share, Outstanding on December 31,2013	$17.76
Weighted Average Exercise Price per Share, Granted	$26.79
Weighted Average Exercise Price per Share, Exercised	$18.57

Employee_Benefit_Plans_Fair_Va

Employee Benefit Plans (Fair Value Stock Option Award) (Details)	5 Months Ended	12 Months Ended
	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefit Plans [Abstract]	'	'	'	'
Risk-free interest rate	2.00%	1.40%	1.00%	1.90%
Expected life (years)	'6 years	'6 years	'6 years	'6 years
Expected Volatility	57.00%	56.00%	56.00%	53.00%
Dividend yield	'	'	'	'

Employee_Benefit_Plans_NonVest

Employee Benefit Plans (Non-Vested Share Awards Activity) (Details) (Restricted Stock [Member], 2009 Long Term Incentive Plan [Member], USD $)	5 Months Ended
	Jun. 03, 2014
Restricted Stock [Member] | 2009 Long Term Incentive Plan [Member]	'
Non-vested restricted share awards outstanding at December 31, 2012	444,495
Restricted Stock, Granted	161,370
Restricted Stock, Vested	-605,865
Weighted Average Grant Date Fair Value, Non-vested restricted share awards outstanding at December 31, 2012	$21.98
Weighted-average grant-date fair value nonvested share awards granted	$25.08
Weighted Average Grant Date Fair Value, Vested	$22.81

Employee_Benefit_Plans_ShareBa

Employee Benefit Plans (Share-Based Compensation Expense and Related Tax Benefits) (Details) (USD $)	5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Income Tax Benefit	'	$2,704	$1,726	$936
Employee Stock Option [Member]	'	'	'	'
Compensation expense	8,248	3,426	2,621	1,497
Non-vested share award [Member]	'	'	'	'
Compensation expense	$11,456	$3,918	$2,096	$1,012

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)	1 Months Ended	5 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2008
	bbl
Loss Contingencies [Line Items]	'	'	'	'	'	'
Operating lease expense	$1.70	$3	$7.50	$2.40	$1.80	'
Commitment amount	38	'	'	'	'	'
Commitment period	'three	'	'	'	'	'
Restricted escrow funds' trust	'	'	'	'	'	15
Misallocated oil volumes	74,000	'	'	'	'	'
Restricted escrow trust funds including accumulated interest	'	'	'	'	'	16.7
Escrow deposit	6	'	'	'	'	'
January 1, 2014 to July 15, 2014 [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Drilling rig commitment per day	107,500	'	'	'	'	'
February 15, 2014 to August 15, 2014 [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Drilling rig commitment per day	111,380	'	'	'	'	'
April 11, 2014 to September 15, 2014 [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Drilling rig commitment per day	112,000	'	'	'	'	'
July 1, 2014 to September 1, 2014 [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Drilling rig commitment per day	107,500	'	'	'	'	'
September 1, 2014 to October 1, 2014 [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Drilling rig commitment per day	107,500	'	'	'	'	'
Maximum [Member]	'	'	'	'	'	'
Loss Contingencies [Line Items]	'	'	'	'	'	'
Value of misallocated oil volumes	$6.90	'	'	'	'	'

Commitments_and_Contingencies_2

Commitments and Contingencies (Schedule of Future Minimum Commitments) (Details) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
Commitments and Contingencies [Abstract]	'
2015	$1,199
2016	1,231
2017	1,010
2018	542
2019	542
Thereafter	135
Future minimum commitments	$4,659

Related_Party_Transactions_Nar

Related Party Transactions (Narrative) (Details) (The South Pass 49 [Member], USD $)	0 Months Ended
	Jun. 03, 2014	Jun. 01, 2014
The South Pass 49 [Member]	'	'
Related Party Transaction [Line Items]	'	'
Purchase price	'	$230,185,000
Borrowings under line of credit	135,000,000	'
Capital contribution from EGC	$95,000,000	'

Comparative_Period_Information2

Comparative Period Information (Schedule of Comparative Period Information) (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

5 Months Ended

6 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Jun. 30, 2014

Jun. 03, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 03, 2014

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Comparative Period Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Total revenue

$60,143

$116,909

[1]

$159,491

[2]

$142,610

[3]

$183,992

[4]

$184,087

$182,349

$276,400

$366,436

'

'

'

Income from operations

13,834

-23,833

[1]

47,396

[2]

20,533

[3]

40,814

[4]

85,552

72,692

23,563

158,244

'

'

'

Income (loss) before income taxes

10,211

'

'

'

'

'

'

-18,461

155,057

'

'

'

Deferred income tax expense

-3,574

'

'

'

'

'

'

-4,495

-56,441

-49,687

-29,900

-14,822

Net income (loss)

6,637

-36,287

[1]

13,331

[2]

-12,058

[3]

-1,284

[4]

69,579

29,037

-22,956

98,616

85,274

58,810

26,611

Basic earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.77

$0.74

($0.59)

$2.51

$2.18

$1.50

$0.66

Diluted earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.75

$0.73

($0.59)

$2.48

$2.15

$1.50

$0.66

Weighted average common shares used in computing earnings (loss) per share:

'

'

'

'

'

'

'

'

'

'

'

'

Basic

'

'

'

'

'

'

'

38,730

38,847

38,730

38,885

39,946

Diluted

'

'

'

'

'

'

'

38,730

39,302

39,236

39,034

40,050

Net cash provided by operating activities

22,209

'

'

'

'

'

'

105,122

192,476

'

'

'

Net cash used in investing activities

-200,929

'

'

'

'

'

'

-258,714

-154,969

'

'

'

Net cash provided by (used in) financing activities

-15,729

'

'

'

'

'

'

344,830

-35,143

'

'

'

Net increase (decrease) in cash and cash equivalents

-194,449

'

'

'

'

'

'

191,238

2,364

'

'

'

Cash and cash equivalents at beginning of period

200,050

'

8,812

'

3,885

'

1,521

8,812

1,521

1,521

'

'

Cash and cash equivalents at end of period

$5,601

$200,050

'

$8,812

'

$3,885

'

$200,050

$3,885

$8,812

$1,521

'

[1]

Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.

[2]

Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.

[3]

The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.

[4]

Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.

Interim_Financial_Information_1

Interim Financial Information (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

5 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2014

Jun. 03, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 03, 2014

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Interim Financial Information [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Revenues

$60,143,000

$116,909,000

[1]

$159,491,000

[2]

$142,610,000

[3]

$183,992,000

[4]

$184,087,000

$182,349,000

$276,400,000

$366,436,000

'

'

'

Cost and expenses

46,309,000

140,742,000

[1]

112,095,000

[2]

122,077,000

[3]

143,178,000

[4]

98,535,000

109,657,000

'

'

'

'

'

Income from operations

13,834,000

-23,833,000

[1]

47,396,000

[2]

20,533,000

[3]

40,814,000

[4]

85,552,000

72,692,000

23,563,000

158,244,000

'

'

'

Net income (loss)

6,637,000

-36,287,000

[1]

13,331,000

[2]

-12,058,000

[3]

-1,284,000

[4]

69,579,000

29,037,000

-22,956,000

98,616,000

85,274,000

58,810,000

26,611,000

Basic earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.77

$0.74

($0.59)

$2.51

$2.18

$1.50

$0.66

Diluted earnings (loss) per share

'

($0.94)

[1]

$0.34

[2]

($0.31)

[3]

($0.03)

[4]

$1.75

$0.73

($0.59)

$2.48

$2.15

$1.50

$0.66

Merger related costs

'

43,500,000

2,200,000

'

'

'

'

'

'

'

'

'

Loss on abandonment activities of non operated interests

'

'

'

'

$22,600,000

'

'

'

'

$20,800,000

'

'

[1]

Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.

[2]

Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.

[3]

The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.

[4]

Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.

Supplementary_Oil_and_Natural_2

Supplementary Oil and Natural Gas Disclosures (Schedule of Estimated Net Proved Reserves, Changes in Estimated Net Proved Reserves and Proved Developed Reserves) (Detail)	6 Months Ended		12 Months Ended
	Jun. 30, 2014		Dec. 31, 2013		Dec. 31, 2012
	MBbls		MBbls		MBbls
Crude Oil (Mbbls) [Member]	'		'		'
Estimated proved reserves, beginning balance	51,517		47,442		27,301
Acquisitions	11,640	[1]	366		16,430	[2]
Sales	'		-1,415		'
Extensions, discoveries and other additions	418	[3]	7,354	[4]	6,388	[5]
Revisions	386	[6]	3,952		1,128
Production	-3,129		-6,182		-3,805
Estimated proved reserves, ending balance	60,832		51,517		47,442
Proved Developed Reserves (Volume)	45,232		39,439		37,908
Proved Undeveloped Reserve Volume	15,600		12,078		9,534
Crude Oil (Mbbls) [Member] | West Delta Field [Member]	'		'		'
Extensions, discoveries and other additions	50		'		'
Gas (Mmcf) [Member]	'		'		'
Estimated proved reserves, beginning balance	173,584		179,939		58,785
Acquisitions	32,731	[1]	209		115,876	[2]
Sales	'		-916		'
Extensions, discoveries and other additions	5,352	[3]	20,247	[4]	10,241	[5]
Revisions	-34,791	[6]	-10,128		4,033
Production	-4,795		-15,767		-8,996
Estimated proved reserves, ending balance	172,081		173,584		179,939
Proved Developed Reserves (Volume)	101,361		107,687		120,687
Proved Undeveloped Reserve Volume	70,720		65,897		59,252
Negative revisions related to the exclusion of estimated fuel gas	35,976		'		'
Increased production to offset the negative revisions	1,185		'		'
Gas (Mmcf) [Member] | West Delta Field [Member]	'		'		'
Extensions, discoveries and other additions	5,040		'		'
Oil Equivalent (Mboe) [Member]	'		'		'
Estimated proved reserves, beginning balance (Energy)	80,448		77,432		37,099
Acquisitions (Energy)	17,095	[1]	401		35,742	[2]
Sales (Energy)	'		-1,568		'
Extensions and discoveries (Energy)	1,310	[3]	10,729	[4]	8,095	[5]
Revisions (Energy)	-5,413	[6]	2,264		1,800
Production (Energy)	-3,928		-8,810		-5,304
Estimated proved reserves, ending balance (Energy)	89,512		80,448		77,432
Proved Developed Reserves (Energy)	62,126		57,387		58,022
Proved Undeveloped Reserves (Energy)	27,386		23,061		19,409
6 Fields [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries fields	'		'		6
6 Fields [Member] | Minimum [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries (Energy)	'		'		18
6 Fields [Member] | Maximum [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries (Energy)	'		'		1.2
3 Fields [Member]	'		'		'
Extensions and discoveries fields	3		'		'
3 Fields [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries fields	'		'		3
3 Fields [Member] | West Delta Field [Member]	'		'		'
Percentage of total extensions and discoveries	68.00%		'		'
3 Fields [Member] | Ship Shoel 208 Field [Member]	'		'		'
Percentage of total extensions and discoveries	23.00%		'		'
3 Fields [Member] | Crude Oil (Mbbls) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions, discoveries and other additions	260		'		'
3 Fields [Member] | Gas (Mmcf) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions, discoveries and other additions	212		'		'
3 Fields [Member] | Oil Equivalent (Mboe) [Member] | West Delta Field [Member]	'		'		'
Extensions and discoveries (Energy)	890		'		'
3 Fields [Member] | Oil Equivalent (Mboe) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions and discoveries (Energy)	295		'		'
3 Fields [Member] | Minimum [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions, discoveries and other additions	'		'		1
12 Fields [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries fields	'		12		'
12 Fields [Member] | Ship Shoel 208 Field [Member]	'		'		'
Percentage of total extensions and discoveries	'		46.00%		'
12 Fields [Member] | Crude Oil (Mbbls) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions, discoveries and other additions	'		3,967		'
12 Fields [Member] | Gas (Mmcf) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions, discoveries and other additions	'		6,035		'
12 Fields [Member] | Oil Equivalent (Mboe) [Member] | Ship Shoel 208 Field [Member]	'		'		'
Extensions and discoveries (Energy)	'		4,973		'
11 Fields [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries fields	'		11		'
Percentage of total extensions and discoveries	'		16.00%		'
11 Fields [Member] | Minimum [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries (Energy)	'		10		'
11 Fields [Member] | Maximum [Member] | Oil Equivalent (Mboe) [Member] | West Delta And Ship Shoal Areas [Member]	'		'		'
Extensions and discoveries (Energy)	'		1.6		'
[1]	Reserves acquired in the acquisitions of the EI Interests and the SP49 Interests.
[2]	Reserves acquired in the acquisitions of the Hilcorp Properties and the ST41 Interests.
[3]	Includes extensions and discoveries across 3 different fields, primarily within our West Delta, Ship Shoal and Eugene Island areas. The West Delta field accounts for 68% of our total extensions and discoveries with 890 Mboe, consisting of 50 Mbbls of oil and 5,040 Mmcf of natural gas. The Ship Shoal 208 field accounts for approximately 23% of our total extensions and discoveries with 295 Mboe, consisting of 260 Mbbls of oil and 212 Mmcf of natural gas.
[4]	Includes extensions and discoveries across 12 different fields, primarily within our Ship Shoal and West Delta areas. The Ship Shoal 208 field accounts for 46% of our total extensions and discoveries with 4,973 Mboe, consisting of 3,967 Mbbls of oil and 6,035 Mmcf of produced gas. The remaining 11 locations account for up to 16% each of total extensions and discoveries with reserves ranging from 10 Mboe to 1.6 Mmboe.
[5]	Includes extensions and discoveries across 6 different fields, primarily within our West Delta and Ship Shoal areas. These extensions and discoveries added volumes ranging from 18 Mboe to 1.2 Mmboe each, with three exceeding 1.0 Mmboe each.
[6]	Natural gas revisions also include negative revisions of approximately 35,976 Mmcf related to the exclusion of estimated fuel gas in our natural gas reserves in the June 30, 2014 reserve volumes. This change in methodology reflects fuel gas as negative natural gas reserves rather than a production cost and does not impact future net cash flows after income taxes or standardized measure of discounted future net cash flows. The negative revisions related to this change in the fuel gas methodology were partially offset by increases of approximately 1,185 Mmcf associated with improved performance of certain wells.

Supplementary_Oil_and_Natural_3

Supplementary Oil and Natural Gas Disclosures (Capitalized Cost for Oil and Natural Gas Producing Activities) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Supplementary Oil and Natural Gas Disclosures [Abstract]	'	'
Capitalized Costs, Proved properties	$2,316,306	$2,307,891
Capitalized Costs, Unproved properties	908,483	39,191
Capitalized costs, Accumulated depreciation, depletion and amortizationmortization	-22,689	-614,068
Net capitalized costs	$3,202,100	$1,733,014

Supplementary_Oil_and_Natural_4

Supplementary Oil and Natural Gas Disclosures (Costs Incurred Associated with Finding, Acquiring and Developing Proved Oil and Natural Gas Reserves) (Details) (USD $)	1 Months Ended	5 Months Ended	6 Months Ended		12 Months Ended
	Jun. 30, 2014	Jun. 03, 2014	Jun. 30, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Acquistions-Proved	'	'	$314,169,000	[1]	$46,047,000	[1]	$706,322,000	[1]	$261,812,000	[1]
Acquisition-Unproved	'	'	9,503,000		2,200,000		7,496,000		14,000
Exploration	'	'	56,079,000		46,100,000		43,338,000		17,129,000
Development	'	'	242,217,000	[2]	303,245,000	[2]	180,938,000	[2]	83,577,000	[2]
Costs incurred	'	'	621,968,000		397,592,000		938,094,000		362,532,000
Liabilities assumed in acquisition	1,086,000	18,165,000	'		23,541,000		132,109,000		'
Asset retirement obligations incurred	'	'	'		1,200,000		1,200,000		200,000
The South Pass 49 [Member]	'	'	'		'		'		'
Acquistions-Proved	'	'	231,000,000		'		'		'
Nexen Acquisition [Member]	'	'	'		'		'		'
Acquistions-Proved	'	'	$83,000,000		'		'		'
[1]	For the six months ended June 30, 2014, includes $231 million associated with the acquisition of the SP 49 Interests and $83 million associated with the acquisition of the EI Interests. See Note 3 bAcquisitions and Dispositionsb of the consolidated financial statements in Part II, Item 8 of this Transition Report for further information.
[2]	Includes our estimates during the years ended December 31, 2013, 2012 and 2011 of incurred asset retirement obligations associated with finding and developing our proved oil and natural gas reserves of $1.2B million, $1.2B millionB and $0.2 million, respectively.

Supplementary_Oil_and_Natural_5

Supplementary Oil and Natural Gas Disclosures (Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Natural Gas Reserves) (Details) (USD $)	6 Months Ended		12 Months Ended
	Jun. 30, 2014		Dec. 31, 2013
Supplementary Oil and Natural Gas Disclosures [Abstract]	'		'
Future cash inflows	$6,704,859,000		$5,937,536,000
Future production costs	-2,126,110,000		-1,957,868,000
Future development costs	-1,161,289,000	[1]	-1,085,440,000	[1]
Future income taxes	-712,700,000		-641,536,000
Future net cash flows after income taxes	2,704,760,000		2,252,692,000
10% annual discount for estimated timing of cash flows	-740,167,000		-603,614,000
Standardized measure of discounted future net cash flows	1,964,593,000		1,649,078,000
Future abandonment and decommissioning costs	558,400,000		569,900,000
Future salvage values	$120,500,000		$25,800,000
[1]	Future development cost as of June 30, 2014 include $558.4 million of estimated abandonment and decommissioning costs, net of $120.5 million of estimated salvage values. Future development costs as of December 31, 2013, include $569.9 million of estimated abandonment and decommissioning costs, net of $25.8 million of estimated salvage values.

Supplementary_Oil_and_Natural_6

Supplementary Oil and Natural Gas Disclosures (Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Applicable to Proved Oil and Natural Gas Reserves) (Details) (USD $)	6 Months Ended		12 Months Ended
	Jun. 30, 2014		Dec. 31, 2013
Supplementary Oil and Natural Gas Disclosures [Abstract]	'		'
Beginning of the period	$1,649,078,000		$1,574,282,000
Sales and transfers of oil and natural gas produced, net of productuin costs	-240,361,000		-513,906,000
Net changes in prices and production costs	-21,599,000	[1]	96,751,000	[1]
Purchase of mineral in place	471,329,000		26,708,000
Sales of minerals in place	'		-64,539,000
Extensions, discoveries and improved recoveries, net of future production costs	49,566,000		363,493,000
Revision of quantity estimates	-325,294,000		84,490,000
Previously estimated development costs incurred during the period	55,888,000		33,920,000
Changes in estimated future development costs	1,560,000		18,229,000
Changes in production rates (timing) and other	170,915,000		-113,022,000
Accretion of discount	210,932,000		197,927,000
Net change in income taxes	-57,421,000		-55,255,000
Net increase (decrease)	315,515,000		74,796,000
End of period	1,964,593,000		1,649,078,000
Future abandonment and decommissioning costs	$558,400,000		$569,900,000
[1]	Our estimated future production costs reflect a decrease related to the previously described change in the fuel gas methodology to reflect the fuel gas as negative natural gas reserves rather than production cost.

Supplementary_Oil_and_Natural_7

Supplementary Oil and Natural Gas Disclosures (Oil and Natural Gas Computed Price Used in Computation of Discounted Future Net Cash Flows) (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2013
Supplementary Oil and Natural Gas Disclosures [Abstract]	'	'
Computed price per barrel of oil	98.58	105.3
Computed prices per mcf of natural gas	4.12	3.73

Supplemental_Condensed_Consoli2

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Balance Sheet) (Details) (USD $)

1 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2012

Jun. 30, 2014

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2014

Jun. 03, 2014

Jun. 30, 2014

Jun. 03, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Jun. 03, 2014

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

Successor Company [Member]

Successor Company [Member]

Successor Company [Member]

Successor Company [Member]

Successor Company [Member]

Successor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Predecessor Company [Member]

Parent Company [Member]

Parent Company [Member]

Guarantor Subsidiaries [Member]

Consolidation, Eliminations [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Parent Company [Member]

Guarantor Subsidiaries [Member]

Guarantor Subsidiaries [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Senior notes, stated percentage

'

'

'

'

'

8.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of ownership interest

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

$5,601

$200,050

$8,812

$3,885

$1,521

'

'

'

$5,601

$200,050

$5,601

$200,050

'

'

$200,050

$8,812

$1,521

$80,128

$33,553

$200,050

$8,812

$1,521

$80,128

$33,553

'

'

'

'

'

'

Trade accounts receivable - net

'

'

'

'

'

'

'

'

72,301

93,007

72,156

'

145

'

91,813

70,707

67,991

'

'

'

70,520

66,994

'

'

187

997

'

'

'

'

Intercompany receivable

'

'

'

'

'

'

'

'

'

'

'

'

26,311

-26,311

'

'

'

'

'

'

39,085

55,575

'

'

'

'

-39,085

-55,575

'

'

Fair value of commodity derivative instruments

'

'

501

'

3,302

'

'

'

'

'

'

'

'

'

'

501

3,302

'

'

'

501

3,302

'

'

'

'

'

'

'

'

Current deferred asset

24,587

'

8,949

'

3,322

'

'

'

24,587

24,587

24,587

'

'

'

8,405

8,949

3,322

'

'

'

8,949

3,322

'

'

'

'

'

'

'

'

Prepaid expenses

'

'

'

'

'

'

'

'

26,521

9,809

26,521

'

'

'

9,729

6,868

9,873

'

'

'

6,868

9,873

'

'

'

'

'

'

'

'

Total current assets

'

'

'

'

'

'

'

'

129,010

327,453

128,865

'

26,456

-26,311

309,997

95,837

86,009

'

'

'

134,735

140,587

'

'

187

997

-39,085

-55,575

'

'

Net property and equipment

3,205,187

'

1,736,431

'

1,598,067

'

'

'

3,205,187

2,941,892

3,034,805

'

170,382

'

1,969,382

1,736,431

1,598,067

'

'

'

1,514,953

1,400,768

'

'

221,478

197,299

'

'

'

'

Investment in affiliates

'

'

'

'

'

'

'

'

'

'

126,638

'

'

-126,638

'

'

'

'

'

'

122,697

111,191

'

'

'

'

-122,697

-111,191

'

'

Goodwill

'

'

'

'

'

'

'

'

327,235

327,235

327,235

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deposit for Nexen Acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,040

'

'

'

'

7,040

'

'

'

'

'

'

'

'

'

Restricted cash

'

'

'

'

'

'

'

'

6,023

6,023

6,023

'

'

'

6,023

6,023

6,023

'

'

'

6,023

6,023

'

'

'

'

'

'

'

'

Fair value of commodity derivative instruments

'

'

238

'

211

'

'

'

'

27

'

'

'

'

27

238

211

'

'

'

238

211

'

'

'

'

'

'

'

'

Deferred financing costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,002

10,106

12,386

'

'

'

10,106

12,386

'

'

'

'

'

'

'

'

Other assets

'

'

'

'

'

'

'

'

317

1,175

226

'

91

'

1,175

2,156

2,931

'

'

'

2,067

2,841

'

'

89

90

'

'

'

'

Total Assets

'

'

'

'

'

'

'

'

3,667,772

3,603,805

3,623,792

'

196,929

-152,949

2,295,606

1,857,831

1,705,627

'

'

'

1,797,859

1,674,007

'

'

221,754

198,386

-161,782

-166,766

'

'

Accounts payable

'

'

'

'

'

'

'

'

90,923

61,938

90,267

'

656

'

61,938

59,431

34,772

'

'

'

58,758

34,740

'

'

673

32

'

'

'

'

Intercompany payables

'

'

'

'

'

'

'

'

'

'

26,311

'

'

-26,311

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to EGC

'

'

'

'

'

'

'

'

4,960

'

4,960

'

'

'

'

'

'

'

'

'

'

'

'

'

39,085

55,575

-39,085

-55,575

'

'

Accrued expenses

'

'

'

'

'

'

'

'

161,518

230,086

161,503

'

15

'

230,086

131,125

117,372

'

'

'

131,111

117,245

'

'

14

127

'

'

'

'

Asset retirement obligations

39,831

39,859

51,601

'

30,179

'

'

'

39,831

43,617

33,357

'

6,474

'

39,859

51,601

30,179

'

'

'

51,601

23,982

'

'

'

6,197

'

'

'

'

Fair value of commodity derivative instruments

26,440

'

29,636

'

10,026

'

'

'

26,440

22,625

26,440

'

'

'

22,625

29,636

10,026

'

'

'

29,636

10,026

'

'

'

'

'

'

'

'

Total current liabilities

'

'

'

'

'

'

'

'

323,672

358,266

342,838

'

7,145

-26,311

354,508

271,793

192,349

'

'

'

271,106

185,993

'

'

39,772

61,931

-39,085

-55,575

'

'

Long-term debt

1,025,566

'

627,355

'

689,911

550,566

497,355

494,911

1,025,566

1,026,407

1,025,566

'

'

'

973,440

627,355

689,911

'

'

'

627,355

689,911

'

'

'

'

'

'

'

'

Asset retirement obligations

232,864

220,302

203,849

'

204,931

'

'

'

232,864

229,755

193,908

'

38,956

'

220,302

203,849

204,931

'

'

'

160,466

187,790

'

'

43,383

17,141

'

'

'

'

Deferred tax liabilities

483,798

'

122,812

'

67,694

'

'

'

483,798

483,591

459,608

'

24,190

'

126,764

122,812

67,694

'

'

'

106,910

59,571

'

'

15,902

8,123

'

'

'

'

Fair value of commodity derivative instruments

2,140

'

2,136

'

3,637

'

'

'

2,140

1,439

2,140

'

'

'

1,439

2,136

3,637

'

'

'

2,136

3,637

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

6

6

6

'

'

'

803

673

1,132

'

'

'

673

1,132

'

'

'

'

'

'

'

'

Total Liabilities

'

'

'

'

'

'

'

'

2,068,046

2,099,464

2,024,066

'

70,291

-26,311

1,677,256

1,228,618

1,159,654

'

'

'

1,168,646

1,128,034

'

'

99,057

87,195

-39,085

-55,575

'

'

Preferred stock, par value $0.001 per share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value $0.001 per share

'

'

'

'

'

'

'

'

'

'

'

'

'

'

41

41

40

'

'

'

41

40

'

'

'

'

'

'

'

'

Additional paid-in capital

'

'

'

'

'

'

'

'

1,599,341

1,504,341

1,599,341

'

85,479

-85,479

538,844

519,114

510,469

'

'

'

519,114

510,469

'

'

85,479

85,479

-85,479

-85,479

'

'

Accumulated other comprehensive income

'

'

'

'

'

'

'

'

-6,252

'

-6,252

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Treasury stock, at cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-38,794

-31,157

-20,477

'

'

'

-31,157

-20,477

'

'

'

'

'

'

'

'

Retained earnings

'

'

'

'

'

'

'

'

6,637

'

6,637

'

41,159

-41,159

118,259

141,215

55,941

'

'

'

141,215

55,941

'

'

37,218

25,712

-37,218

-25,712

'

'

Total stockholders' equity

'

'

'

'

'

'

'

'

1,599,726

1,504,341

1,599,726

'

126,638

-126,638

618,350

629,213

545,973

491,045

473,116

'

629,213

545,973

'

'

122,697

111,191

-122,697

-111,191

'

'

Total liabilities and stockholders' equity

'

'

'

'

'

'

'

'

$3,667,772

$3,603,805

$3,623,792

'

$196,929

($152,949)

$2,295,606

$1,857,831

$1,705,627

'

'

'

$1,797,859

$1,674,007

'

'

$221,754

$198,386

($161,782)

($166,766)

'

'

Supplemental_Condensed_Consoli3

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Statement of Operations) (Details) (USD $)

1 Months Ended

2 Months Ended

3 Months Ended

5 Months Ended

6 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 03, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Jun. 03, 2014

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Total revenue

$60,143

$116,909

[1]

$159,491

[2]

$142,610

[3]

$183,992

[4]

$184,087

$182,349

$276,400

$366,436

'

'

'

Accretion of liability for asset retirement obligations

2,022

'

'

'

'

'

'

11,771

'

28,299

15,565

'

Total costs and expenses

46,309

140,742

[1]

112,095

[2]

122,077

[3]

143,178

[4]

98,535

109,657

'

'

'

'

'

Income from operations

13,834

-23,833

[1]

47,396

[2]

20,533

[3]

40,814

[4]

85,552

72,692

23,563

158,244

'

'

'

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

-19,420

'

-32,361

-13,305

-5,870

Income (loss) before income taxes

10,211

'

'

'

'

'

'

-18,461

155,057

'

'

'

Deferred income tax expense

-3,574

'

'

'

'

'

'

-4,495

-56,441

-49,687

-29,900

-14,822

Net income (loss)

6,637

-36,287

[1]

13,331

[2]

-12,058

[3]

-1,284

[4]

69,579

29,037

-22,956

98,616

85,274

58,810

26,611

Successor Company [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

59,811

'

'

'

'

'

'

'

'

'

'

'

Other

332

'

'

'

'

'

'

'

'

'

'

'

Total revenue

60,143

'

'

'

'

'

'

'

'

'

'

'

Lease operating

17,746

'

'

'

'

'

'

'

'

'

'

'

Transportation

299

'

'

'

'

'

'

'

'

'

'

'

Exploration expenditures and dry hole costs

'

'

'

'

'

'

'

'

'

'

'

'

Impairments

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation, depletion and amortization

22,775

'

'

'

'

'

'

'

'

'

'

'

Accretion of liability for asset retirement obligations

2,022

'

'

'

'

'

'

'

'

'

'

'

General and administrative

2,617

'

'

'

'

'

'

'

'

'

'

'

Taxes, other than on earnings

850

'

'

'

'

'

'

'

'

'

'

'

Gain on sale of assets

'

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

'

'

'

'

Total costs and expenses

46,309

'

'

'

'

'

'

'

'

'

'

'

Income from operations

13,834

'

'

'

'

'

'

'

'

'

'

'

Interest income

4

'

'

'

'

'

'

'

'

'

'

'

Interest expense

-3,627

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

Loss on early extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

'

Total other expense

-3,623

'

'

'

'

'

'

'

'

'

'

'

Income (loss) before income taxes

10,211

'

'

'

'

'

'

'

'

'

'

'

Deferred income tax expense

-3,574

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

6,637

'

'

'

'

'

'

'

'

'

'

'

Successor Company [Member] | Parent Company [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

53,860

'

'

'

'

'

'

'

'

'

'

'

Other

114

'

'

'

'

'

'

'

'

'

'

'

Total revenue

53,974

'

'

'

'

'

'

'

'

'

'

'

Lease operating

15,282

'

'

'

'

'

'

'

'

'

'

'

Transportation

299

'

'

'

'

'

'

'

'

'

'

'

Depreciation, depletion and amortization

20,950

'

'

'

'

'

'

'

'

'

'

'

Accretion of liability for asset retirement obligations

1,602

'

'

'

'

'

'

'

'

'

'

'

General and administrative

2,605

'

'

'

'

'

'

'

'

'

'

'

Taxes, other than on earnings

35

'

'

'

'

'

'

'

'

'

'

'

Total costs and expenses

40,773

'

'

'

'

'

'

'

'

'

'

'

Income from operations

13,201

'

'

'

'

'

'

'

'

'

'

'

Interest income

4

'

'

'

'

'

'

'

'

'

'

'

Interest expense

-3,627

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from equity investments

412

'

'

'

'

'

'

'

'

'

'

'

Total other expense

-3,211

'

'

'

'

'

'

'

'

'

'

'

Income (loss) before income taxes

9,990

'

'

'

'

'

'

'

'

'

'

'

Deferred income tax expense

-3,353

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

6,637

'

'

'

'

'

'

'

'

'

'

'

Successor Company [Member] | Guarantor Subsidiaries [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

5,951

'

'

'

'

'

'

'

'

'

'

'

Other

218

'

'

'

'

'

'

'

'

'

'

'

Total revenue

6,169

'

'

'

'

'

'

'

'

'

'

'

Lease operating

2,464

'

'

'

'

'

'

'

'

'

'

'

Depreciation, depletion and amortization

1,825

'

'

'

'

'

'

'

'

'

'

'

Accretion of liability for asset retirement obligations

420

'

'

'

'

'

'

'

'

'

'

'

General and administrative

12

'

'

'

'

'

'

'

'

'

'

'

Taxes, other than on earnings

815

'

'

'

'

'

'

'

'

'

'

'

Total costs and expenses

5,536

'

'

'

'

'

'

'

'

'

'

'

Income from operations

633

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) before income taxes

633

'

'

'

'

'

'

'

'

'

'

'

Deferred income tax expense

-221

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

412

'

'

'

'

'

'

'

'

'

'

'

Successor Company [Member] | Consolidation, Eliminations [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from equity investments

-412

'

'

'

'

'

'

'

'

'

'

'

Total other expense

-412

'

'

'

'

'

'

'

'

'

'

'

Income (loss) before income taxes

-412

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

-412

'

'

'

'

'

'

'

'

'

'

'

Predecessor Company [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

'

'

'

'

'

'

'

274,772

'

688,743

422,529

348,207

Other

'

'

'

'

'

'

'

1,628

'

4,295

1,104

120

Total revenue

'

'

'

'

'

'

'

276,400

'

693,038

423,633

348,327

Lease operating

'

'

'

'

'

'

'

72,302

'

165,841

94,850

70,281

Transportation

'

'

'

'

'

'

'

1,475

'

3,568

615

779

Exploration expenditures and dry hole costs

'

'

'

'

'

'

'

26,239

'

26,555

18,799

14,268

Impairments

'

'

'

'

'

'

'

61

'

2,937

8,883

32,466

Depreciation, depletion and amortization

'

'

'

'

'

'

'

85,127

'

200,359

113,581

104,624

Accretion of liability for asset retirement obligations

'

'

'

'

'

'

'

11,771

'

28,299

15,565

15,942

General and administrative

'

'

'

'

'

'

'

51,434

'

28,137

23,208

18,741

Taxes, other than on earnings

'

'

'

'

'

'

'

4,384

'

11,490

13,007

14,365

Gain on sale of assets

'

'

'

'

'

'

'

'

'

-28,681

'

'

Other

'

'

'

'

'

'

'

44

'

34,942

4,678

9,735

Total costs and expenses

'

'

'

'

'

'

'

252,837

'

473,447

293,186

281,201

Income from operations

'

'

'

'

'

'

'

23,563

'

219,591

130,447

67,126

Interest income

'

'

'

'

'

'

'

17

'

99

136

102

Interest expense

'

'

'

'

'

'

'

-22,621

'

-52,368

-28,568

-17,548

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

-19,420

'

-32,361

-13,305

-5,870

Loss on early extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

-2,377

Total other expense

'

'

'

'

'

'

'

-42,024

'

-84,630

-41,737

-25,693

Income (loss) before income taxes

'

'

'

'

'

'

'

-18,461

'

134,961

88,710

41,433

Deferred income tax expense

'

'

'

'

'

'

'

-4,495

'

-49,687

-29,900

-14,822

Net income (loss)

'

'

'

'

'

'

'

-22,956

'

85,274

58,810

26,611

Predecessor Company [Member] | Parent Company [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

'

'

'

'

'

'

'

245,684

'

606,743

318,749

245,567

Other

'

'

'

'

'

'

'

399

'

689

15,152

15,007

Total revenue

'

'

'

'

'

'

'

246,083

'

607,432

333,901

260,574

Lease operating

'

'

'

'

'

'

'

62,116

'

140,605

71,002

51,618

Transportation

'

'

'

'

'

'

'

1,474

'

3,548

611

766

Exploration expenditures and dry hole costs

'

'

'

'

'

'

'

26,345

'

22,265

18,790

14,045

Impairments

'

'

'

'

'

'

'

61

'

2,937

8,883

32,532

Depreciation, depletion and amortization

'

'

'

'

'

'

'

76,481

'

178,427

92,689

82,168

Accretion of liability for asset retirement obligations

'

'

'

'

'

'

'

9,736

'

23,196

10,551

9,013

General and administrative

'

'

'

'

'

'

'

51,434

'

28,137

22,845

18,281

Taxes, other than on earnings

'

'

'

'

'

'

'

377

'

1,084

1,162

-733

Gain on sale of assets

'

'

'

'

'

'

'

'

'

-28,219

'

'

Other

'

'

'

'

'

'

'

44

'

34,072

5,496

9,940

Total costs and expenses

'

'

'

'

'

'

'

228,068

'

406,052

232,029

217,630

Income from operations

'

'

'

'

'

'

'

18,015

'

201,380

101,872

42,944

Interest income

'

'

'

'

'

'

'

17

'

99

136

102

Interest expense

'

'

'

'

'

'

'

-22,621

'

-52,368

-28,568

-17,548

Gain (loss) on derivative instruments

'

'

'

'

'

'

'

-19,420

'

-32,361

-13,305

-5,870

Loss on early extinguishment of debt

'

'

'

'

'

'

'

'

'

'

'

-2,377

Income (loss) from equity investments

'

'

'

'

'

'

'

3,529

'

11,506

18,945

15,532

Total other expense

'

'

'

'

'

'

'

-38,495

'

-73,124

-22,792

-10,161

Income (loss) before income taxes

'

'

'

'

'

'

'

-20,480

'

128,256

79,080

32,783

Deferred income tax expense

'

'

'

'

'

'

'

-2,476

'

-42,982

-20,270

-6,172

Net income (loss)

'

'

'

'

'

'

'

-22,956

'

85,274

58,810

26,611

Predecessor Company [Member] | Guarantor Subsidiaries [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Oil and natural gas

'

'

'

'

'

'

'

29,088

'

82,000

103,780

102,640

Other

'

'

'

'

'

'

'

1,229

'

3,606

952

113

Total revenue

'

'

'

'

'

'

'

30,317

'

85,606

104,732

102,753

Lease operating

'

'

'

'

'

'

'

10,186

'

25,236

23,848

18,663

Transportation

'

'

'

'

'

'

'

1

'

20

4

13

Exploration expenditures and dry hole costs

'

'

'

'

'

'

'

-106

'

4,290

9

223

Impairments

'

'

'

'

'

'

'

'

'

'

'

-66

Depreciation, depletion and amortization

'

'

'

'

'

'

'

8,646

'

21,932

20,892

22,456

Accretion of liability for asset retirement obligations

'

'

'

'

'

'

'

2,035

'

5,103

5,014

6,929

General and administrative

'

'

'

'

'

'

'

'

'

'

15,363

15,460

Taxes, other than on earnings

'

'

'

'

'

'

'

4,007

'

10,406

11,845

15,098

Gain on sale of assets

'

'

'

'

'

'

'

'

'

-462

'

'

Other

'

'

'

'

'

'

'

'

'

870

-818

-205

Total costs and expenses

'

'

'

'

'

'

'

24,769

'

67,395

76,157

78,571

Income from operations

'

'

'

'

'

'

'

5,548

'

18,211

28,575

24,182

Income (loss) before income taxes

'

'

'

'

'

'

'

5,548

'

18,211

28,575

24,182

Deferred income tax expense

'

'

'

'

'

'

'

-2,019

'

-6,705

-9,630

-8,650

Net income (loss)

'

'

'

'

'

'

'

3,529

'

11,506

18,945

15,532

Predecessor Company [Member] | Consolidation, Eliminations [Member]

'

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

'

'

-15,000

-15,000

Total revenue

'

'

'

'

'

'

'

'

'

'

-15,000

-15,000

General and administrative

'

'

'

'

'

'

'

'

'

'

-15,000

-15,000

Total costs and expenses

'

'

'

'

'

'

'

'

'

'

-15,000

-15,000

Income (loss) from equity investments

'

'

'

'

'

'

'

-3,529

'

-11,506

-18,945

-15,532

Total other expense

'

'

'

'

'

'

'

-3,529

'

-11,506

-18,945

-15,532

Income (loss) before income taxes

'

'

'

'

'

'

'

-3,529

'

-11,506

-18,945

-15,532

Net income (loss)

'

'

'

'

'

'

'

($3,529)

'

($11,506)

($18,945)

($15,532)

[1]

Included in costs and expenses for the period from April 1, 2014 through June 3, 2014 are merger related costs totaling $43.5 million.

[2]

Included in costs and expenses for the three months ended March 31, 2014 are merger related costs totaling $2.2 million.

[3]

The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.

[4]

Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.

Supplemental_Condensed_Consoli4

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Statement of Cash Flows) (Details) (USD $)	1 Months Ended	5 Months Ended	6 Months Ended	1 Months Ended		5 Months Ended	12 Months Ended			5 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 03, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Jun. 03, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2011
				Successor Company [Member]	Successor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]	Predecessor Company [Member]
					Parent Company [Member]					Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Guarantor Subsidiaries [Member]	Guarantor Subsidiaries [Member]	Guarantor Subsidiaries [Member]	Consolidation, Eliminations [Member]
Net cash provided by operating activities	$22,209	$105,122	$192,476	$22,209	$22,163	$105,122	$387,559	$213,871	$171,252	$102,307	$356,597	$190,851	$136,245	$30,962	$23,020	$35,007	'
Decrease in restricted cash	'	'	'	'	'	'	'	'	2,466	'	'	'	2,466	'	'	'	'
Property acquisitions	'	'	'	-141,886	-141,886	-60,495	-27,560	-578,372	-235,486	-57,680	-27,560	-575,372	-235,486	'	-3,000	'	'
Deposit for Nexen Acquisition	'	'	'	'	'	'	-7,040	'	'	'	-7,040	'	'	'	'	'	'
Exploration and development expenditures	'	'	'	-58,976	-58,930	-197,968	-322,040	-184,850	-76,003	-197,968	-284,073	-165,308	-40,996	-37,967	-19,542	-35,007	'
Other property and equipment additions	'	'	'	-67	-67	-251	-2,016	-1,743	-1,568	-251	-2,016	-1,265	-1,568	'	-478	'	'
Proceeds from sale of assets	'	'	'	'	'	'	52,317	'	'	'	45,312	'	'	7,005	'	'	'
Net cash used in investing activities	-200,929	-258,714	-154,969	-200,929	-200,883	-258,714	-306,339	-764,965	-310,591	-255,899	-275,377	-741,945	-275,584	-30,962	-23,020	-35,007	'
Proceeds from indebtedness	'	'	'	475,000	475,000	345,000	'	509,313	203,794	345,000	'	509,313	203,794	'	'	'	'
Repayments of indebtedness	'	'	'	-475,000	-475,000	'	-65,000	-20,000	'	'	-65,000	-20,000	'	'	'	'	'
Advances to EGC	'	'	'	-15,729	-15,729	'	'	'	'	'	'	'	'	'	'	'	'
Deferred financing costs	'	'	'	'	'	-170	-674	-8,469	-6,646	-170	-674	-8,469	-6,646	'	'	'	'
Purchase of shares into treasury	'	'	'	'	'	'	-9,640	-8,798	-11,353	'	-9,640	-8,798	-11,353	'	'	'	'
Exercise of stock options	'	'	'	'	'	'	1,385	441	119	'	1,385	441	119	'	'	'	'
Net cash provided by (used in) financing activities	-15,729	344,830	-35,143	-15,729	-15,729	344,830	-73,929	472,487	185,914	344,830	-73,929	472,487	185,914	'	'	'	'
Net increase in cash and cash equivalents	-194,449	191,238	2,364	-194,449	-194,449	191,238	7,291	-78,607	46,575	191,238	7,291	-78,607	46,575	'	'	'	'
Cash and cash equivalents at beginning of period	200,050	8,812	1,521	200,050	200,050	8,812	1,521	80,128	33,553	8,812	1,521	80,128	33,553	'	'	'	'
Cash and cash equivalents at end of period	$5,601	$200,050	$3,885	$5,601	$5,601	$200,050	$8,812	$1,521	$80,128	$200,050	$8,812	$1,521	$80,128	'	'	'	'