Supplemental Information on Oil & Natural Gas Exploration and Production Activities (unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

Supplemental Information on Oil & Natural Gas Exploration and Production Activities (unaudited)

Schedule of aggregate capitalized costs relating to oil and gas activities

December 31,	2013			2012			2011
Oil and natural gas properties:
Proved properties	$	12,939,857		$	13,246,115		$	13,246,115
	12,939,857			13,246,115			13,246,115
Less:
Accumulated depreciation, depletion and amortization	(2,386,439		)	(2,657,247		)	(2,463,179		)
Property impairment	(10,550,118		)	(10,540,042		)	(10,282,343		)
Total	$	3,300		$	48,826		$	500,593

Schedule of costs incurred in oil and gas exploration and development activities

	2013			2012		2011
Oil and natural gas properties:
Exploration	$	—		$	—	$	(1,809	)
Development	(1,036		)	—		35,510
Total	$	(1,036	)	$	—	$	33,701

Schedule of results of operations from oil and gas producing activities

	2013			2012			2011
Oil and gas producing activities:
Oil sales	$	63,552		$	246,317		$	917,019
Natural gas sales	34,322			57,343			241,530
Production expenses	(73,849		)	(106,924		)	(350,905		)
Accretion of asset retirement obligation	(905		)	(19,845		)	(12,182		)
Depreciation , depletion and amortization	(30,508		)	(171,180		)	(313,136		)
Property impairment expense	(10,076		)	(257,699		)	—
Results of operations from producing activities	$	(17,464	)	$	(251,988	)	$	482,326
Depletion rate per BOE	$	13.04		$	26.24		$	16.91

Schedule of changes in estimated net proved developed crude oil and natural gas reserves

	Oil(BBL) (1)		Gas(mcf)		BOE (2)
Net proved reserves for properties owned by the Partnership
Reserves at December 31, 2010	47,700		231,180		86,230
Reserves sold	(32,473	)	(74,438	)	(44,880	)
Revisions of previous estimates	1,469		(15,246	)	(1,071	)
Production	(10,056	)	(50,796	)	(18,522	)
Reserves at December 31, 2011	6,640		90,700		21,757
Revisions of previous estimates	(2,769	)	(50,258	)	(11,146	)
Production	(2,951	)	(21,442	)	(6,524	)
Reserves at December 31, 2012	920		19,000		4,087
Reserves sold	(100	)	(238	)	(140	)
Revisions of previous estimates	6		(6,679	)	(1,107	)
Production	(766	)	(9,443	)	(2,340	)
Reserves at December 31, 2013	60		2,640		500

(1) Oil includes both oil and natural gas liquids

(2) BOE (barrels of oil equivalent) is calculated by converting 6 MCF of natural gas to 1 BBL of oil. A BBL (barrel) of oil is one stock tank barrel, or 42 U.S. gallons liquid volume, of crude oil or other liquid hydrocarbons.

Schedule of discounted future net cash flows

December 31,	2013			2012			2011
Crude oil and natural gas properties owned by the Partnership:
Future cash inflows	$	15,850		$	148,640		$	1,076,880
Future production costs	(12,490		)	(90,140		)	(324,970		)
Future development costs	—			—			—
Future net cash flows	3,360			58,500			751,910
Effect of discounting net cash flows at 10%	(60		)	(3,190		)	(96,690		)
Discounted future net cash flows	$	3,300		$	55,310		$	655,220

Schedule of changes in the standardized measure of discounted future net cash flows relating to proved crude oil and natural gas reserves

December 31,	2013			2012			2011
Crude oil and natural gas properties owned by the Partnership:
Standardized measure at beginning of period	$	55,310		$	655,220		$	2,097,800
Extensions and discoveries
Net change in sales price, net of production costs	(20,131		)	(254,621		)	171,135
Revisions of quantity estimates	(7,797		)	(150,827		)	(28,147		)
Net changes in estimated future development costs				—			—
Changes in production timing rates	(5,323		)	(83,093		)	(92,615		)
Accretion of discount	5,531			65,522			209,780
Sales net of production costs	(23,120		)	(176,891		)	(795,462		)
Sales of minerals in place	(1,170		)	—			(907,271		)
Net increase (decrease)	(52,010		)	(599,910		)	(1,442,580		)
Standardized measure at end of year	$	3,300		$	55,310		$	655,220