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, 2018 and 2017 (in thousands):



	Years Ended December 31,
	2018		2017
Proved oil and gas properties	$	6,503	$	5,704
Unproved properties		23		—
Total proved and unproved oil and gas properties	$	6,526	$	5,704
Less accumulated depreciation, depletion and amortization		(1,722)		(984)
Net oil and gas properties	$	4,804	$	4,720

Oil and Gas Related Costs

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



	Years Ended December 31,
	2018		2017
Property acquisitions proved	$	164	$	—
Property acquisitions unproved		23		93
Exploration cost		590		69
Development cost		243		—
Total	$	1,020	$	162

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):



	Years Ended December 31,
	2018		2017
Revenues	$	5,871	$	4,683
Production costs and taxes		(3,591)		(3,444)
Depreciation, depletion and amortization		(722)		(796)
Income (loss) from oil and gas producing activities	$	1,558	$	443

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 Company’s operating tax loss carry-forward position.

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, 2016, 2017 and 2018. All of the Company’s proved reserves are located in the United States of America.



	Oil (MBbl)	Gas (MMcf)	MBOE
Proved reserves at December 31, 2016	730	—	730
Revisions of previous estimates	195	—	195
Improved recovery	—	—	—
Purchase of reserves in place	—	—	—
Extensions and discoveries	47	—	47
Production	(102)	—	(102)
Sales of reserves in place	—	—	—
Proved reserves at December 31, 2017	870	—	870
Revisions of previous estimates	223	—	223
Improved recovery	—	—	—
Purchase of reserves in place	13	—	13
Extensions and discoveries	86	—	86
Production	(98)	—	(98)
Sales of reserves in place	—	—	—
Proved reserves at December 31, 2018	1,094	—	1,094

Proved developed reserves at:
December 31, 2016	730	—	730
December 31, 2017	832	—	832
December 31, 2018	976	—	976

Proved undeveloped reserves at:
December 31, 2016	—	—	—
December 31, 2017	38	—	38
December 31, 2018	118	—	118

The Company’s Proved Undeveloped Reserves at December 31, 2018 included 7 locations and at December 31, 2017 included 3 locations, and no locations at December 31, 2016 and 2015. During 2016 and 2015, all Proved Undeveloped locations were removed from the Company’s Proved Reserves primarily due to the low oil prices experienced during these years. Increases in prices allowed the company to include 3 Proved Undeveloped locations in its December 31, 2017 reserves and 7 Proved Undeveloped locations in its December 31, 2018 reserves. Although the Company completed a well during 2018 that was not included in Proved Reserves at the end of 2017 and therefore contributed to extensions and discoveries, the primary factor causing the revisions as well as the extensions and discoveries during 2018 levels was related to higher oil prices that enabled the Company to consider certain properties as becoming economic or remaining economic longer and to consequently increase the oil volumes included in Proved Reserves.

The following table identifies the Company’s net proved 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 12/31/2018						Year Ended 12/31/2017						Year Ended 12/31/2016
	Oil		Gas		Total		Oil		Gas		Total		Oil		Gas		Total
Total proved reserves year-end reserve report	$	13,976		—	$	13,976	$	8,170		—	$	8,170	$	5,815		—	$	5,815
Proved developed producing reserves (PDP)	$	12,534		—	$	12,534	$	7,065		—	$	7,065	$	5,397		—	$	5,397
% of PDP reserves to total proved reserves		90%		—		90%		87%		—		87%		93%		—		93%
Proved developed non- producing reserves	$	739		—	$	739	$	1,082		—	$	1,082	$	418		—	$	418
% of PDNP reserves to total proved reserves		5%		—		5%		13%		—		13%		7%		—		7%
Proved undeveloped reserves (PUD)	$	703		—	$	703	$	23		—	$	23	$	—		—	$	—
% of PUD reserves to total proved reserves		5%		—		5%		—		—		—		—		—		—

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):



	Years Ended December 31,
	2018		2017		2016
Future cash inflows	$	65,871	$	39,889	$	27,253
Future production costs and taxes		(35,877)		(23,343)		(16,270)
Future development costs		(2,833)		(1,586)		(553)
Future income tax expenses		—		—		—
Future net cash flows		27,161		14,960		10,430

Discount at 10% for timing of cash flows		(13,185)		(6,790)		(4,615)
Standardized measure of discounted future net cash flows	$	13,976	$	8,170	$	5,815

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):



	Years Ended December 31,
	2018		2017		2016
Balance, beginning of year	$	8,170	$	5,815	$	8,287
Sales, net of production costs and taxes		(2,611)		(1,239)		(2,037)
Discoveries and extensions, net of costs		798		123		35
Purchase of reserves in place		143		—		—
Sale of reserves in place		—		—		(10)
Net changes in prices and production costs		4,304		1,780		(863)
Revisions of quantity estimates		2,180		1,611		(412)
Previously estimated development cost incurred during the year		210		—		—
Changes in future development costs		78		(228)		196
Changes in timing and other		(4)		(164)		(20)
Accretion of discount		708		472		639
Net change in income taxes		—		—		—
Balance, end of year	$	13,976	$	8,170	$	5,815

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, 2018, 2017, and 2016 were $60.21, and $45.83, and $37.35 per barrel of oil, respectively. The Company’s proved reserves as of December 31, 2018, 2017 and 2016 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 cost such as general corporate overhead or interest expense.