15. Supplemental Oil and Gas Information (unaudited)

Information with respect to the Companys 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 Companys 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, 2014 and 2013 (in thousands):


		Years Ended December 31,
		2014			2013
Proved oil and gas properties	$	49,388		$	45,101
Unproved properties		462			736
Total proved and unproved oil and gas properties	$	49,850		$	45,837

Less accumulated depreciation, depletion and amortization		(24,437	)		(21,714	)
Net oil and gas properties	$	25,413		$	24,123

Oil and Gas Related Costs

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


	Years Ended December 31,
		2014		2013		2012
Property acquisitions proved	$	-	$	-	$	-
Property acquisitions unproved		598		488		188
Exploration cost		2,367		914		4,608
Development cost		864		998		2,649
Total	$	3,829	$	2,400	$	7,445

Results of Operations from Oil and Gas Producing Activities

The following table sets forth the Companys results of operations from oil and gas producing activities (in thousands):


	Years Ended December 31,
		2014			2013			2012

Revenues	$	13,260		$	15,325		$	19,885
Production costs and taxes		(4,876	)		(4,854	)		(5,610	)
Depreciation, depletion and amortization		(2,766	)		(2,606	)		(3,044	)
Income from oil and gas producing activities	$	5,618		$	7,865		$	11,231

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

Estimated Quantities of Oil and Gas Reserves

The following table sets forth the Companys net proved oil and gas reserves and the changes in net proved oil and gas reserves for the years ended December 31, 2012, 2013 and 2014. All of the Companys proved reserves are located in the United States of America.


	Oil (MBbl)		Gas (MMcf)		MBOE
Proved reserves at December 31, 2011	2,591		4		2,592

Revisions of previous estimates	(337	)	61		(327	)
Improved recovery	-		-		-
Purchase of reserves in place	-		-		-
Extensions and discoveries	186		-		186
Production	(227	)	(43	)	(234	)
Sales of reserves in place	-		-		-

Proved reserves at December 31, 2012	2,213		22		2,217

Revisions of previous estimates	(153	)	16		(151	)
Improved recovery	-		-		-
Purchase of reserves in place	-		-		-
Extensions and discoveries	170		-		170
Production	(166	)	(38	)	(172	)
Sales of reserves in place	(24	)	-		(24	)

Proved reserves at December 31, 2013	2,040		-		2,040

Revisions of previous estimates	(253	)	-		(253	)
Improved recovery	-		-		-
Purchase of reserves in place	-		-		-
Extensions and discoveries	164		-		164
Production	(154	)	-		(154	)
Sales of reserves in place	-		-		-
Proved reserves at December 31, 2014	1,797		-		1,797

Proved developed reserves at:
December 31, 2011	1,939		4		1,940
December 31, 2012	1,822		22		1,826
December 31, 2013	1,575		-		1,575
December 31, 2014	1,438		-		1,438

Proved undeveloped reserves at:
December 31, 2011	652		-		652
December 31, 2012	391		-		391
December 31, 2013	465		-		465
December 31, 2014	359		-		359

The Companys Proved Undeveloped Reserves at December 31, 2014 included 27 locations as compared to 29 locations at December 31, 2013. During 2014, one of the PUDs contributing reserves of 12 MBbl that existed at December 31, 2013 was drilled and moved into proved developed reserves, 9 PUDs contributing reserves of 155 MBbl were dropped from the PUD reserves at December 31, 2014, and there was a 50 MBbl downward revision in PUD reserves. These reductions were partially offset by the addition of 8 PUD locations which contributed 111 MBbl of reserves at December 31, 2014. The future development cost related to the Companys Proved Undeveloped locations at December 31, 2014 was approximately $8.7 million. The Company intends to fund the drilling of these locations through operating cash flow and, as needed, supplement the funding by drawing on the Companys credit facility.

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 12/31/14							Year Ended 12/31/13							Year Ended 12/31/12
		Oil		Gas		Total			Oil		Gas		Total			Oil			Gas		Total
Total proved reserves year-end
reserve report	$	40,417		-	$	40,417		$	47,856		-	$	47,856		$	53,906		$	5	$	53,911
Proved developed producing
reserves (PDP)	$	32,059		-	$	32,059		$	34,440		-	$	34,440		$	42,621		$	5	$	42,626
% of PDP reserves to total proved
reserves		79	%	-		79	%		72	%	-		72	%		79	%		-		79	%
Proved developed non-producing
reserves	$	2,956		-	$	2,956		$	4,868		-	$	4,868		$	3,234			-	$	3,234
% of PDNP reserves to total proved
reserves		7	%	-		7	%		10	%	-		10	%		6	%		-		6	%
Proved undeveloped reserves (PUD)
	$	5,402		-	$	5,402		$	8,548		-	$	8,548		$	8,051			-	$	8,051
% of PUD reserves to total proved
reserves		14	%	-		14	%		18	%	-		18	%		15	%		-		15	%

Standardized Measure of Discounted Future Net Cash Flows

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


		Years Ended December 31,
		2014			2013			2012
Future cash inflows	$	158,792		$	183,801		$	194,941
Future production costs and taxes		(71,951	)		(82,307	)		(82,069	)
Future development costs		(10,014	)		(11,162	)		(7,894	)
Future income tax expenses		(13,092	)		(18,910	)		(19,472	)
Future net cash flows		63,735			71,422			85,506

Discount at 10% for timing of cash flows		(29,204	)		(32,714	)		(40,152	)
Standardized measure of discounted future net cash flows	$	34,531		$	38,708		$	45,354

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


		Years Ended December 31,
		2014			2013			2012
Balance, beginning of year	$	38,708		$	45,354		$	51,909
Sales, net of production costs and taxes		(8,385	)		(10,471	)		(14,275	)
Discoveries and extensions, net of costs		4,231			4,047			6,967
Purchase of reserves in place		-			-			-
Sale of reserves in place		-			(767	)		-
Net changes in prices and production costs		(829	)		(1,277	)		(6,067	)
Revisions of quantity estimates		(6,610	)		(4,306	)		(9,883	)
Previously estimated development cost incurred during the year		508			3,149			8,760
Changes in future development costs		(1,913	)		(1,392	)		(1,919	)
Changes in production rates (timing) and other		1,312			368			(5,657	)
Accretion of discount		4,247			4,593			6,223
Net change in income taxes		3,262			(590	)		9,296
Balance, end of year	$	34,531		$	38,708		$	45,354

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 oil prices used for December 31, 2014, 2013, and 2012, were $88.34, $90.11, $88.08 per barrel of oil respectively. The gas price used in 2012 was $2.76. The Companys proved reserves as of December 31, 2014, 2013 and 2012 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. No deduction has been made for depreciation, depletion or any indirect costs such as general corporate overhead or interest expense.