Supplemental Gas and Oil Information (Unaudited) (Tables)

12 Months Ended

Dec. 31, 2015

Extractive Industries [Abstract]

Changes in Proved Reserve Quantities

Reserve quantity information and a reconciliation of changes in proved reserve quantities included within the Partnership are as follows:

	Gas (Mcf)			Oil (Bbls)
Balance, December 31, 2013		1,628,400			5,700
Revisions(1)		(61,900	)		400
Production		(225,600	)		(600	)
Balance, December 31, 2014		1,340,900			5,500
Revisions (2)		(1,064,300	)		(4,300	)
Production		(185,400	)		(600	)
Balance, December 31, 2015 (3)		91,200			600

(1) The downward revision in natural gas forecasts is primarily due to forecasts adjustments in order to reflect actual production.  The upward revision in oil forecasts is primarily due to forecast adjustments in order to better reflect actual production.

(2) The downward revision in natural gas forecasts is primarily due to forecast adjustments in order to reflect actual production; the downward revision in oil forecasts is primarily due to a decrease in the SEC base pricing from the prior year, resulting in a shorter economic life.

(3) We have experienced significant downward revisions of our natural gas and oil reserves volumes and values in 2015 due to the recent significant declines in commodity prices. The proved reserves quantities and future net cash flows were estimated under the SEC’s standardized measure using an unweighted 12-month average pricing based on the gas and oil prices on the first day of each month during the year ended December 31, 2015, including adjustments related to regional price differentials and energy content.  The SEC’s standardized measure of reserve quantities and discounted future net cash flows may not represent the fair market value of the Partnership’s gas and oil equivalent reserves due to anticipated future changes in gas and oil commodity prices. Accordingly, such information should not serve as a basis in making any judgment on the potential value of recoverable reserves or in estimating future results of operations.

Capitalized Costs Relating to Gas and Oil Producing Activities

Capitalized Costs Related to Gas and Oil Producing Activities. The components of capitalized costs related to gas and oil producing activities of the Partnership during the periods indicated were as follows:

	Years Ended December 31,
	2015			2014
Natural gas and oil properties:
Leasehold interest	$	332,100		$	332,100
Wells and related equipment		25,756,100			25,756,500
Accumulated depletion, accretion and impairment		(25,398,000	)		(24,589,200	)
Net capitalized costs	$	690,200		$	1,499,400

Results of Operations for Gas and Oil Producing Activities

Results of Operations from Gas and Oil Producing Activities. The results of operations related to the Partnership’s gas and oil producing activities during the periods indicated were as follows:

	Years Ended December 31,
	2015			2014
Revenues	$	335,500		$	873,300
Production costs		(406,600	)		(537,200	)
Depletion		(40,400	)		(228,700	)
Impairment		(768,600	)		(1,881,400	)
	$	(880,100	)	$	(1,774,000	)

Standardized Measure of Discounted Future Cash Flows

Standardized Measure of Discounted Future Cash Flows. The following schedule presents the standardized measure of estimated discounted future net cash flows relating to the Partnership’s proved gas and oil reserves. The estimated future production was priced at a twelve-month average for the years ended December 31, 2015 and 2014, adjusted only for regional price differentials and energy content. The resulting estimated future cash inflows were reduced by estimated future costs to produce the proved reserves based on year-end cost levels and includes the effect on cash flows of settlement of asset retirement obligations on gas and oil properties. The future net cash flows were reduced to present value amounts by applying a 10% discount factor. The standardized measure of future cash flows was prepared using the prevailing economic conditions existing at the dates presented and such conditions continually change. Accordingly, such information should not serve as a basis in making any judgment on the potential value of recoverable reserves or in estimating future results of operations:

	Years Ended December 31,
	2015 (1)			2014
Future cash inflows	$	191,900		$	5,513,300
Future production costs		(187,400	)		(4,046,600	)
Future net cash flows		4,500			1,466,700
Less 10% annual discount for estimated timing of cash flows		(100	)		(419,600	)
Standardized measure of discounted future net cash flows	$	4,400		$	1,047,100

(1) We have experienced significant downward revisions of our natural gas and oil reserves volumes and values in 2015 due to the recent significant declines in commodity prices. The proved reserves quantities and future net cash flows were estimated under the SEC’s standardized measure using an unweighted 12-month average pricing based on the gas and oil prices on the first day of each month during the year ended December 31, 2015, including adjustments related to regional price differentials and energy content.  The SEC’s standardized measure of reserve quantities and discounted future net cash flows may not represent the fair market value of the Partnership’s gas and oil equivalent reserves due to anticipated future changes in gas and oil commodity prices.  Accordingly, such information should not serve as a basis in making any judgment on the potential value of recoverable reserves or in estimating future results of operations.