15. Supplemental Oil and Gas Information (unaudited)

Information with respect to the Company's oil and gas producing activities is presented in the following tables. Estimates of reserves quantities, as well as future production and discounted cash flows before income taxes, were determined by LaRoche Petroleum Consultants Ltd. All of the Company's reserves were located in the United States.

Capitalized Costs Related to Oil and Gas Producing Activities

The table below reflects our capitalized costs related to our oil and gas producing activities at December 31, 2011 and 2010 (in thousands):


	Years Ended December 31,
	2011			2010
Proved oil and gas properties	$	36,002		$	27,837
Unproved properties		268			189
Total proved and unproved oil and gas properties	$	36,270		$	28,026

Less accumulate depreciation, depletion and amortization		(16,064	)		(13,869	)
Net oil and gas properties	$	20,206		$	14,157

Oil and Gas Related Costs

The following table sets forth information concerning costs incurred related to the Company's oil and gas property acquisition, exploration and development activities (in thousands):


	Years Ended December 31,
	2011		2010		2009
Property acquisitions proved	$	-	$	-	$	-
Property acquisitions unproved		-		-		-
Exploration cost		708		80		-
Development cost		7,607		3,453		1,020
Total	$	8,315	$	3,533	$	1,020

Results of Operations from Oil and Gas Producing Activities

The following table sets forth the Company's results of operations from oil and gas producing activities.

(in thousands)


	Year Ended December 31,
	2011			2010			2009

Revenues	$	16,862		$	12,876		$	9,711
Production costs and taxes		(5,310	)		(5,308	)		(5,225	)
Depreciation, depletion and amortization		(2,195	)		(1,938	)		(1,800	)
Income from oil and gas producing activities	$	9,357		$	5,630		$	2,686

In the presentation above, no deduction has been made for indirect costs such as corporate overhead or interest expense. No income taxes are reflected above due to the Company's operating tax loss carry-forwards.

Estimated Quantities of Oil and Gas Reserves

The following table sets forth the Company's net proved oil and gas reserves and the changes in net proved oil and gas reserves for the years ended December 31, 2011, 2010 and 2009.


			Oil (MBbls)			Gas (MMcf)		MBOE
Proved reserves at December 31, 2008			1,248			910		1,399

Revisions of previous estimates	(1	)	1,203			(721	)	1,084
Improved recovery			-			-		-
Purchase of reserves in place			-			-		-
Extensions and discoveries			-			-		-
Production			(171	)		(73	)	(183	)
Sales of reserves in place			(7	)	-	-		(7	)

Proved reserves at December 31,			2,273			116		2,293

Revisions of previous estimates			360			(64	)	350
Improved recovery


Purchase of reserves in place
Extensions and discoveries	37				35
Production	(174	)	(25	)	(178	)
Sales of reserves in place

Proved reserves at December 31, 2010	2,496		27		2,500

Revisions of previous estimates	10		3		11
Improved recovery	-		-		-
Purchase of reserves in place	-		-		-
Extensions and discoveries	274		-		274
Production	(189	)	(26	)	(193	)
Sales of reserves in place	-		-		-

Proved reserves at December 31, 2011	2,591		4		2,592

Proved developed reserves at:
December 31, 2009	1,579		116		1,598
December 31, 2010	1,800		27		1,804
December 31, 2011	1,939		4		1,940

Proved undeveloped reserves at:
December 31, 2009	694		-		694
December 31, 2010	696		-		696
December 31, 2011	652		-		652

The following table identifies the reserve value by category and the respective present values, before income taxes, discounted at 10% as a percentage of total proved reserves (in thousands):


	Year Ended 12/31/11								Year Ended 12/31/10								Year Ended 12/31/09
	Oil			Gas		Total			Oil			Gas		Total			Oil			Gas			Total
Total proved reserves year-end reserve report	$	69,748		$	15	$	69,763		$	48,331		$	13	$	48,344		$	27,964		$	223		$	28,187

Proved developed producing reserves (PDP)	$	46,606		$	15	$	46,621		$	28,974		$	13	$	28,987		$	15,476		$	223		$	15,699

% of PDP reserves to total proved reserves		67	%		-		67	%		60	%		-		60	%		55	%		1	%		56	%

Proved developed non-producing reserves	$	3,977			-	$	3,977		$	7,476			-	$	7,476		$	5,185			-		$	5,185
% of PDNP reserves to total proved reserves		6	%		-		6	%		15	%		-		15	%		18	%		-			18	%

Proved undeveloped reserves (PUD)	$	19,165			-	$	19,165		$	11,881			-	$	11,881		$	7,303			-		$	7,303
% of PUD reserves to total proved reserves		27	%		-		27	%		25	%		-		25	%		26	%		-			26	%

Standardized Measure of Discounted Future Net Cash Flows

The standardized measure of discounted future net cash flows from the Company's proved oil and gas reserves is presented in the following table (in thousands):


	December 31,
	2011			2010			2009
Future cash inflows	$	229,366		$	180,569		$	122,844
Future production costs and taxes		(82,086	)		(70,771	)		(56,550	)
Future development costs		(12,611	)		(13,283	)		(11,039	)
Future income tax expenses		(34,750	)		-			-
Future net cash flows flows		99,919			96,515			55,255

Discount at 10% for timing of cash flows		(48,010	)		(48,171	)		(27,068	)
Standardized measure of discounted future net cash flows	$	51,909		$	48,344		$	28,187

The following are the principal sources of change in the standardized measure of discounted future net cash flows from the Company's proved oil and gas reserves (in thousands):


	December 31,
	2011			2010			2009
Balance, beginning of year	$	48,344		$	28,187		$	10,293
Sales, net of production costs and taxes		(11,552	)		(7,568	)		(4,486	)
Discoveries and extensions, net of costs		10,923			2,099			-
Purchase of reserves in place		-			-			-
Sale of reserves in place		-			-			(109	)
Net changes in prices and production costs		15,428			15,554			10,433
Revisions of quantity estimates		343			8,873			17,705
Previously estimated development cost incurred during the year		5,346			3,806			28
Changes in future development costs		(1,109	)		(3,168	)		(5,489	)
Changes in production rates and other		(2,336	)		(2,037	)		(1,217	)
Accretion of discount		4,376			2,598			1,029
Net change in income taxes		(17,854	)		-			-
Balance, end of year	$	51,909		$	48,344		$	28,187

Estimated future net cash flows represent an estimate of future net revenues from the production of proved reserves using average sales prices, along with estimates of the operating costs, production taxes and future development and abandonment cost (less salvage value) necessary to produce such reserves. Future income taxes were calculated by applying the statutory federal and state income tax rates to pre-tax future net cash flows, net of the tax basis of the properties and utilizing available tax loss carryforwards related to oil and gas operations. The prices used for December 31, 2011,2010, and 2009, were $88.53, $72.30, $53.81 per barrel of oil and $4.16, $4.89, $4.61, per MCF of gas, respectively. The Company's proved reserves as of December 31, 2011, 2010 and 2009 were measured by using commodity prices based on the twelve month unweighted arithmetic average of the first day of the month price for the period January through December. The Company's proved reserves as of December 31, 2008 were measured by using end of year prices. No deduction has been made for depreciation, depletion or any indirect costs such as general corporate overhead or interest expense.