Supplemental Information About Oil & Natural Gas Producing Activities (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2016

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure

The following table sets forth the capitalized costs incurred in the Company’s oil and gas production, exploration, and development activities:

	Successor		Predecessor
	October 11, 2016 through December 31, 2016		January 1, 2016 through October 10, 2016		Year Ended December 31,
(in thousands)					2015		2014
Acquisition costs:
Proved properties	$	561,251	$	16,386	$	14,268	$	5,758
Unproved properties	1,905,660		39,399		28,955		16,409
Development costs	44,602		53,512		87,452		324,802
Exploration costs	844		—		84		—
Total	$	2,512,357	$	109,297	$	130,759	$	346,969

Results of Operations for Oil and Gas Producing Activities Disclosure

The results of operations for oil and natural gas producing activities (excluding corporate overhead and interest costs) are presented below:

	Successor		Predecessor
	October 11, 2016 through December 31, 2016		January 1, 2016 through October 10, 2016			Year Ended December 31,
(in thousands)						2015			2014
Revenues:
Oil, natural gas and NGL sales	$	29,717	$	69,116		$	90,460		$	131,825
Costs:
Lease operating expenses	3,541		11,036			21,173			17,690
Severance and ad valorem taxes	1,636		3,696			5,021			6,875
Transportation, processing, gathering and other operating expenses	2,187		4,583			5,732			4,772
Depletion, amortization and accretion of asset retirement obligations	14,486		62,228			89,350			68,981
Abandonment expense and impairment of unproved properties	—		2,545			7,619			20,025
Exploration	844		—			84			—
Contract termination and rig stacking	—		—			2,387			—
Income tax expense (benefit)	—		(406		)	(572		)	1,524
Results of operations	$	7,023	$	(14,566	)	$	(40,334	)	$	11,958

Oil and Gas Net Production, Average Sales Price and Average Production Costs Disclosure

The following table summarizes the average price during the 12-month period, determined as the unweighted arithmetic average of the first-day-of-the-month for the periods from October 11, 2016, through December 31, 2016 (Successor) and January 1, 2016, through October 10, 2016 (Predecessor) and for the years ended December 31, 2015 and 2014. The following prices, as adjusted for transportation, quality, and basis differentials, were used in the calculation of the standardized measure of discounted future net cash flows (“standardized measure”):

	Successor		Predecessor
	October 11, 2016 through December 31, 2016		January 1, 2016 through October 10, 2016		Year Ended December 31,
					2015		2014
Oil (per Bbl)	$	38.49	$	36.98	$	41.85	$	84.94
Gas (per Mcf)	0.98		1.24		1.71		4.70
NGLs (per Bbl)	14.59		13.28		13.94		22.70

Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities

The table below presents a summary of changes in the Company’s estimated proved reserves:

	Successor						Predecessor
	October 11, 2016, through December 31, 2016						January 1, 2016, through October 10, 2016
	Crude Oil (MBbls)		Natural Gas (MMcf)		Natural Gas Liquids (MBbls)		Crude Oil (MBbls)		Natural Gas (MMcf)		Natural Gas Liquids (MBbls)
Total proved reserves:
Beginning of period	30,091		36,801		4,506		23,199		32,442		3,851
Extensions and discoveries	7,063		12,219		1,225		5,851		6,410		773
Revisions of previous estimates	184		16,445		983		1,025		(1,521	)	(110	)
Purchases of reserves in place	9,651		83,992		5,152		1,600		2,130		245
Divestitures of reserves in place	—		—		—		—		—		—
Production	(523	)	(1,113	)	(96	)	(1,584	)	(2,660	)	(253	)
End of period	46,466		148,344		11,770		30,091		36,801		4,506
Proved developed reserves:
Beginning of period	11,346		14,973		1,927		9,347		12,711		1,603
End of period	14,551		42,190		3,618		11,346		14,973		1,927
Proved undeveloped reserves:
Beginning of period	18,745		21,828		2,579		13,852		19,731		2,248
End of period	31,914		106,154		8,152		18,745		21,828		2,579

	Predecessor
	Year Ended December 31, 2015						Year Ended December 31, 2014
	Crude Oil (MBbls)		Natural Gas (MMcf)		Natural Gas Liquids (MBbls)		Crude Oil (MBbls)		Natural Gas (MMcf)		Natural Gas Liquids (MBbls)
Total proved reserves:
Beginning of period	19,850		27,414		1,551		18,510		6,968		525
Extensions and discoveries	9,444		11,927		1,432		16,122		22,575		1,127
Revisions of previous estimates	(5,109	)	(5,204	)	995		56		178		180
Purchases of reserves in place	844		1,363		204		162		192		23
Divestitures of reserves in place	—		—		—		(13,572	)	(387	)	(69	)
Production	(1,830	)	(3,058	)	(331	)	(1,428	)	(2,112	)	(235	)
End of period	23,199		32,442		3,851		19,850		27,414		1,551
Proved developed reserves:
Beginning of period	8,026		11,959		766		6,021		4,837		382
End of period	9,347		12,711		1,603		8,026		11,959		766
Proved undeveloped reserves:
Beginning of period	11,823		15,455		785		12,489		2,131		143
End of period	13,852		19,731		2,248		11,823		15,455		785

Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure

The following table presents the Company’s standardized measure of discounted future net cash flows:

	Successor			Predecessor
	October 11, 2016 through December 31, 2016			January 1, 2016 through October 10, 2016			Year Ended December 31,
(in thousands)							2015			2014
Future cash inflows	$	2,105,585		$	1,217,641		$	1,079,962		$	1,850,205
Future development costs	(482,162		)	(297,559		)	(277,837		)	(440,366		)
Future production costs	(640,306		)	(413,410		)	(450,058		)	(457,236		)
Future income tax expenses	(136,587		)	(5,614		)	(6,643		)	(10,834		)
Future net cash flows	846,530			501,058			345,424			941,769
10% discount to reflect timing of cash flows	(471,438		)	(291,345		)	(210,355		)	(575,886		)
Standardized measure of discounted future net cash flows	$	375,092		$	209,713		$	135,069		$	365,883

Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows

The following summarizes the principal sources of change in the standardized measure of discounted future net cash flows:

	Successor			Predecessor
(in thousands)	October 11, 2016 through December 31, 2016			January 1, 2016 through October 10, 2016
Standardized measure of discounted future net cash flows, beginning of period	$	209,713		$	135,069
Sales of oil, natural gas and NGLs, net of production costs	(22,354		)	(49,801		)
Purchase of minerals in place	127,842			10,145
Divestiture of minerals in place	—			—
Extensions and discoveries, net of future development costs	55,825			46,438
Change in estimated development costs	10,891			11,743
Net change in prices and production costs	(978		)	6,661
Change in estimated future development costs	571			28,998
Revisions of previous quantity estimates	20,190			3,673
Accretion of discount	4,753			11,319
Net change in income taxes	(47,990		)	(1,568		)
Net change in timing of production and other	16,629			7,036
Standardized measure of discounted future net cash flows, end of period	$	375,092		$	209,713

	Predecessor
	Year Ended December 31,
(in thousands)	2015			2014
Standardized measure of discounted future net cash flows, beginning of period	$	365,883		$	371,307
Sales of oil, natural gas and NGLs, net of production costs	(58,534		)	(102,488		)
Purchase of minerals in place	14,416			5,650
Divestiture of minerals in place	—			(242,344		)
Extensions and discoveries, net of future development costs	57,894			312,532
Change in estimated development costs	16,100			10,386
Net change in prices and production costs	(494,734		)	(3,027		)
Change in estimated future development costs	247,642			2,935
Revisions of previous quantity estimates	(51,342		)	924
Accretion of discount	37,517			13,561
Net change in income taxes	1,601			(2,762		)
Net change in timing of production and other	(1,374		)	(791		)
Standardized measure of discounted future net cash flows, end of period	$	135,069		$	365,883