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

12 Months Ended

Dec. 31, 2012

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

Schedule of aggregate capitalized costs relating to oil and gas activities

December 31,	2012			2011			2010
Oil and natural gas properties:
Proved properties	$	13,246,115		$	13,246,115		$	21,979,751
	13,246,115			13,246,115			21,979,751
Less:
Accumulated depreciation, depletion and amortization	(2,657,247		)	(2,463,179		)	(3,569,405		)
Property impairment	(10,540,042		)	(10,282,343		)	(17,249,916		)
Total	$	48,826		$	500,593		$	1,160,430

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

	2012		2011			2010
Oil and natural gas properties:
Exploration	$	—	$	(1,809	)	$	9,200
Development	—		35,510			368,186
Total	$	—	$	33,701		$	377,386

Schedule of results of operations from oil and gas producing activities

	2012			2011			2010
Oil and gas producing activities:
Oil sales	$	246,317		$	917,019		$	1,036,282
Natural gas sales	57,343			241,530			485,595
Production expenses	(106,924		)	(350,905		)	(315,265		)
Accretion of asset retirement obligation	(19,845		)	(12,182		)	(16,448		)
Depreciation , depletion and amortization	(171,180		)	(313,136		)	(540,316		)
Property impairment expense	(257,699		)	—			—
Results of operations from producing activities	$	(251,988	)	$	482,326		$	649,848
Depletion rate per BOE	$	26.24		$	16.91		$	17.78

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, 2009	41,710		188,020		73,046
Revisions of previous estimates	20,258		139,882		43,572
Production	(14,268	)	(96,722	)	(30,388	)
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

(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,	2012			2011			2010
Crude oil and natural gas properties owned by the Partnership:
Future cash inflows	$	148,640		$	1,076,880		$	4,998,080
Future production costs	(90,140		)	(324,970		)	(2,355,900		)
Future development costs	—			—			—
Future net cash flows	58,500			751,910			2,642,180
Effect of discounting net cash flows at 10%	(3,190		)	(96,690		)	(544,380		)
Discounted future net cash flows	$	55,310		$	655,220		$	2,097,800

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

December 31,	2012			2011			2010
Crude oil and natural gas properties owned by the Partnership:
Standardized measure at beginning of period	$	655,220		$	2,097,800		$	1,323,360
Extensions and discoveries
Net change in sales price, net of production costs	(254,621		)	171,135			599,658
Revisions of quantity estimates	(150,827		)	(28,147		)	1,060,019
Net changes in estimated future development costs	—			—			—
Changes in production timing rates	(83,093		)	(92,615		)	172,591
Accretion of discount	65,522			209,780			132,336
Sales net of production costs	(176,891		)	(795,462		)	(1,190,164		)
Sales of minerals in place	—			(907,271		)	—
Net increase (decrease)	(599,910		)	(1,442,580		)	774,440
Standardized measure at end of year	$	55,310		$	655,220		$	2,097,800