Supplemental Oil and Gas Disclosures (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2013

Oil and Gas Exploration and Production Industries Disclosures [Abstract]

Capitalized Costs Relating to Oil and Gas Producing Activities

The accompanying table presents information concerning the Company’s oil and gas producing activities as required by ASC 932-235, “Disclosures about Oil and Gas Producing Activities.”  Capitalized costs relating to oil and gas producing activities are as follows:

	Years Ended December 31
	2012									2013
	Total			U.S.			Canada			Total			U.S.			Canada
	(In thousands)
Proved oil and gas properties	$	563,317		$	531,971		$	31,346		$	564,755		$	530,996		$	33,759
Unproved properties	2,089			—			2,089			—			—			—
Total	565,406			531,971			33,435			564,755			530,996			33,759
Accumulated depreciation, depletion, amortization and impairment	(383,469		)	(356,255		)	(27,214		)	(413,704		)	(381,283		)	(32,421		)
Net capitalized costs	$	181,937		$	175,716		$	6,221		$	151,051		$	149,713		$	1,338

Cost Incurred in Oil and Gas Property Acquisition and Development Activities

Cost incurred in oil and gas property acquisition and development activities are as follows:

	Years Ended December 31
	2011						2012						2013
	Total		U.S.		Canada		Total		U.S.		Canada		Total		U.S.		Canada
	(In thousands)
Development costs	$	46,735	$	32,471	$	14,264	$	56,318	$	48,283	$	8,035	$	93,878	$	91,325	$	2,553
Exploration costs	8,410		8,410		—		—		—		—		—		—		—
Property acquisition costs	—		—		—		7,200		7,200		—		—		—		—
Unproved	1,100		—		1,100		989		—		989		—		—		—
	$	56,245	$	40,881	$	15,364	$	64,507	$	55,483	$	9,024	$	93,878	$	91,325	$	2,553

Results of Operations for Oil and Gas Producing Activities

The results of operations for oil and gas producing activities for the three years ended December 31, 2011, 2012 and 2013 are as follows:

	Years Ended December 31,
	2011									2012									2013
	Total			U.S.			Canada			Total			U.S.			Canada			Total			U.S.			Canada
	(In thousands)
Revenues	$	64,615		$	63,105		$	1,510		$	68,499		$	65,590		$	2,909		$	94,275		$	92,268		$	2,007
Production costs	(27,347		)	(26,552		)	(795		)	(31,419		)	(29,166		)	(2,253		)	(33,871		)	(31,642		)	(2,229		)
Depreciation, depletion, and amortization	(15,595		)	(14,914		)	(681		)	(22,767		)	(20,704		)	(2,063		)	(26,072		)	(25,028		)	(1,044		)
Proved property impairment	—			—			—			(19,774		)	—			(19,774		)	(6,025		)	—			(6,025		)
General and administrative	(2,352		)	(1,698		)	(654		)	(2,679		)	(1,980		)	(699		)	(3,350		)	(2,471		)	(879		)
Results of operations from oil and gas producing activities (excluding corporate overhead and interest costs)	$	19,321		$	19,941		$	(620	)	$	(8,140	)	$	13,740		$	(21,880	)	$	24,957		$	33,127		$	(8,170	)
Depletion rate per barrel of oil equivalent	$	12.26		$	11.96		$	27.58		$	15.59		$	14.74		$	37.48		$	16.59		$	16.32		$	27.37

Proved Developed and Undeveloped Reserves

Proved reserves were estimated in accordance with guidelines established by the SEC and the FASB, which require that reserve estimates be prepared under existing economic and operating conditions with no provision for price and cost escalations except by contractual arrangements; therefore, the average prior 12-month-first-day-of-the-month commodity prices and year-end costs were used in estimating reserve volumes and future net cash flows for the periods presented.

	Total						United States						Canada
	Oil/NGL		Gas		Oil Equivalents		Oil/NGL		Gas		Oil Equivalents		Oil/NGL		Gas		Oil Equivalents
	(MBbl)		(MMcf)		(MBoe)		(MBbl)		(MMcf)		(MBoe)		(MBbl)		(MMcf)		(MBoe)
	(In thousands)
Proved developed and undeveloped reserves:
Balance at December 31, 2010	9,794		84,913		23,947		9,718		84,523		23,806		76		390		141
Revisions of previous estimates	2,290		(13,009	)	122		2,290		(13,009	)	122		—		—		—
Extensions and discoveries	2,703		4,393		3,435		2,326		1,837		2,632		377		2,556		803
Sales of minerals in place	—		—		—		—		—		—		—		—		—
Production	(568	)	(4,222	)	(1,272	)	(554	)	(4,160	)	(1,247	)	(14	)	(62	)	(25	)
Balance at December 31, 2011	14,219		72,075		26,232		13,780		69,191		25,313		439		2,884		919
Revisions of previous estimates	1,574		(7,470	)	328		1,774		(5,786	)	809		(200	)	(1,684	)	(481	)
Extensions and discoveries	5,809		6,983		6,973		5,809		6,983		6,973		—		—		—
Purchases of minerals in place	1		69		13		1		69		13		—		—		—
Sales of minerals in place	(850	)	(6,376	)	(1,913	)	(850	)	(6,376	)	(1,913	)	—		—		—
Production	(797	)	(4,097	)	(1,481	)	(763	)	(3,982	)	(1,427	)	(34	)	(115	)	(54	)
Balance at December 31, 2012	19,956		61,184		30,152		19,751		60,099		29,768		205		1,085		384
Revisions of previous estimates	999		(5,123	)	145		1,073		(4,804	)	270		(74	)	(319	)	(125	)
Extensions and discoveries	10,746		3,610		11,348		10,746		3,610		11,348		—		—		—
Purchases of minerals in place	—		—		—		—		—		—		—		—		—
Sales of minerals in place	(7,748	)	(8,141	)	(9,105	)	(7,748	)	(8,141	)	(9,105	)	—		—		—
Production	(1,000	)	(3,421	)	(1,570	)	(976	)	(3,343	)	(1,533	)	(24	)	(78	)	(37	)
Balance at December 31, 2013	22,953		48,109		30,970		22,846		47,421		30,748		107		688		222

	Total			United States			Canada
	Oil/NGL	Gas	Oil Equivalents	Oil/NGL	Gas	Oil Equivalents	Oil/NGL	Gas	Oil Equivalents
	(MBbl)	(MMcf)	(MBoe)	(MBbl)	(MMcf)	(MBoe)	(MBbl)	(MMcf)	(MBoe)
	(In thousands)
Proved Developed Reserves:
December 31, 2011	7,761	42,582	14,858	7,433	40,451	14,175	328	2,131	683
December 31, 2012	8,650	41,220	15,520	8,531	40,723	15,318	119	497	202
December 31, 2013	8,310	31,572	13,572	8,284	31,424	13,521	26	148	51
Proved Undeveloped Reserves:
December 31, 2011	6,460	29,493	11,376	6,348	28,740	11,138	112	753	238
December 31, 2012	11,306	19,964	14,634	11,220	19,376	14,450	86	588	184
December 31, 2013	14,640	16,537	17,397	14,560	15,996	17,226	80	541	171

Future Net Cash Inflows after Income Taxes Discounted At 10% Annual Discount Rate to Arrive At Standardized Measure

Future net cash inflows after income taxes were discounted using a 10% annual discount rate to arrive at the Standardized Measure. The table below sets forth the Standardized Measure of our proved oil and gas reserves for the three years ended December 31, 2011, 2012 and 2013:

	Years Ended December 31,
	2011									2012									2013
	Total			U.S.			Canada			Total			U.S.			Canada			Total			U.S.			Canada
	(In thousands)
Future cash inflows	$	1,471,352		$	1,420,013		$	51,339		$	1,784,920		$	1,766,515		$	18,405		$	2,244,846		$	2,234,632		$	10,214
Future production costs	(544,970		)	(532,056		)	(12,914		)	(642,706		)	(634,903		)	(7,803		)	(754,722		)	(751,058		)	(3,664		)
Future development costs	(228,804		)	(224,254		)	(4,550		)	(328,554		)	(324,704		)	(3,850		)	(467,206		)	(463,456		)	(3,750		)
Future income tax expense	(106,839		)	(104,279		)	(2,560		)	(149,625		)	(149,625		)	—			(244,394		)	(244,394		)	—
Future net cash flows	590,739			559,424			31,315			664,035			657,283			6,752			778,524			775,724			2,800
Discount	(321,657		)	(310,516		)	(11,141		)	(385,890		)	(383,271		)	(2,619		)	(437,539		)	(436,077		)	(1,462		)
Standardized Measure of discounted future net cash relating to proved reserves	$	269,082		$	248,908		$	20,174		$	278,145		$	274,012		$	4,133		$	340,985		$	339,647		$	1,338

Analysis of Changes in Standardized Measure

The following is an analysis of the changes in the Standardized Measure:

	Year Ended December 31,
	2011			2012			2013
	(In thousands)
Standardized Measure, beginning of year	$	196,993		$	269,082		$	278,145
Sales and transfers of oil and gas produced, net of production costs	(37,171		)	(37,080		)	(60,403		)
Net change in prices and development and production costs from prior year	92,886			60,710			169,969
Extensions, discoveries, and improved recovery, less related costs	47,765			73,236			156,456
Sales of minerals in place	—			(20,089		)	(125,533		)
Purchased of minerals in place	—			131			—
Revisions of previous quantity estimates	1,329			3,355			2,930
Change in timing and other	(23,501		)	(88,309		)	(62,861		)
Change in future income tax expense	(28,918		)	(9,799		)	(45,532		)
Accretion of discount	19,699			26,908			27,814
Standardized Measure, end of year	$	269,082		$	278,145		$	340,985

Oil and Gas Prices Considered In Standardized Measure of Discounted Future Net Cash Flows

The standardized measure is based on the following oil and gas prices over the life of the properties as of the following dates:

	Year Ended December 31,
	2011		2012		2013
Oil (per Bbl) (1)	$	96.19	$	95.14	$	97.33
Gas (per MMbtu) (2)	$	4.16	$	2.86	$	3.67
Oil (per Bbl) (3)	$	88.58	$	88.26	$	95.90
Gas (per MMBtu) (4)	$	3.73	$	2.61	$	3.65
NGL’s (per Bbl) (5)	$	50.21	$	36.76	$	31.98

_____________________

(1) The quoted oil price for the year ended December 31, 2011, 2012 and 2013 is the 12-month average first-day-of-the-month West Texas Intermediate spot price for each month of 2011, 2012 and 2013.

(2) The quoted gas price for the year ended December 31, 2011, 2012 and 2013 is the 12-month average first-day-of-the-month Henry Hub spot price for each month of 2011, 2012 and 2013.

(3) The oil price is the realized price at the wellhead as of December 31 of each year after the appropriate differentials have been applied.

(4) The gas price is the realized price at the wellhead as of December 31 of each year after the appropriate differentials have been applied.

(5) The NGL price is the realized price as of December 31 of each year after the appropriate differentials have been applied.