Atlas Resources Public #18-2009 10-Q 21 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2016shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Entity Registrant Name	ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.
Entity Central Index Key	1,433,833
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Common Stock, Shares Outstanding	0

CONDENSED BALANCE SHEETS

CONDENSED BALANCE SHEETS - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash	$ 258,200	$ 170,900
Accounts receivable trade–affiliate	1,262,800	1,332,000
Current portion of derivative assets	108,700	1,012,600
Total current assets	1,629,700	2,515,500
Gas and oil properties, net	33,359,400	35,360,600
Long-term asset retirement receivable-affiliate	196,900	136,900
Total assets	35,186,000	38,013,000
Current liabilities:
Accrued liabilities	65,600	49,700
Put premiums payable-affiliate		197,700
Total current liabilities	65,600	247,400
Asset retirement obligations	3,337,000	3,225,100
Commitments and contingencies (Note 6)
Partners’ capital:
Managing general partner’s interest	2,265,900	2,384,400
Limited partners’ interest (22,928.90 units)	29,517,300	32,155,400
Accumulated other comprehensive income	200	700
Total partners’ capital	31,783,400	34,540,500
Total liabilities and partners’ capital	$ 35,186,000	$ 38,013,000

CONDENSED BALANCE SHEETS (Paren

CONDENSED BALANCE SHEETS (Parenthetical)	Sep. 30, 2016shares
Statement Of Financial Position [Abstract]
Limited partners' units	22,928.90

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
REVENUES
Natural gas	$ 1,353,500	$ 1,355,400	$ 3,762,600	$ 5,571,600
Gain on mark-to-market derivatives	14,900	369,300	21,700	593,900
Total revenues	1,368,400	1,724,700	3,784,300	6,165,500
COSTS AND EXPENSES
Production	678,300	935,700	2,178,500	3,014,000
Depletion	635,100	673,500	2,001,200	2,086,400
Impairment		186,200		186,200
Accretion of asset retirement obligations	37,300	43,700	111,900	130,900
General and administrative	39,000	38,500	118,300	114,100
Total costs and expenses	1,389,700	1,877,600	4,409,900	5,531,600
Net (loss) income	(21,300)	(152,900)	(625,600)	633,900
Allocation of net (loss) income:
Managing general partner	116,700	36,400	227,400	461,700
Limited partners	$ (138,000)	$ (189,300)	$ (853,000)	$ 172,200
Net (loss) income per limited partnership unit	$ (6)	$ (8)	$ (37)	$ 8

CONDENSED STATEMENTS OF COMPREH

CONDENSED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Statement Of Income And Comprehensive Income [Abstract]
Net (loss) income	$ (21,300)	$ (152,900)	$ (625,600)	$ 633,900
Other comprehensive loss:
Difference in estimated hedge receivable		(49,900)		(148,900)
Reclassification adjustment to net (loss) income of mark-to-market gains on cash flow hedges	(200)	49,400	(500)	147,300
Total other comprehensive loss	(200)	(500)	(500)	(1,600)
Comprehensive (loss) income	$ (21,500)	$ (153,400)	$ (626,100)	$ 632,300

CONDENSED STATEMENT OF CHANGES

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL - 9 months ended Sep. 30, 2016 - USD ($)	Total	Managing General Partner	Limited Partners	Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2015	$ 34,540,500	$ 2,384,400	$ 32,155,400	$ 700
Participation in revenues, costs and expenses:
Net production revenues	1,584,100	467,200	1,116,900
Gain on mark-to-market derivatives	21,700		21,700
Depletion	(2,001,200)	(175,500)	(1,825,700)
Accretion of asset retirement obligations	(111,900)	(31,300)	(80,600)
General and administrative	(118,300)	(33,000)	(85,300)
Net (loss) income	(625,600)	227,400	(853,000)
Other comprehensive loss	(500)			(500)
Distributions to partners	(2,131,000)	(345,900)	(1,785,100)
Ending balance at Sep. 30, 2016	$ 31,783,400	$ 2,265,900	$ 29,517,300	$ 200

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS - USD ($)	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows from operating activities:
Net (loss) income	$ (625,600)	$ 633,900
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depletion	2,001,200	2,086,400
Impairment		186,200
Non-cash loss on derivative value	705,700	317,800
Accretion of asset retirement obligations	111,900	130,900
Changes in operating assets and liabilities:
Decrease in accounts receivable trade-affiliate	69,200	1,692,400
Increase in asset retirement receivable-affiliate	(60,000)	(93,700)
Increase (decrease) in accrued liabilities	15,900	(14,300)
Net cash provided by operating activities	2,218,300	4,939,600
Cash flows from investing activities:
Proceeds from sale of tangible equipment		36,100
Net cash provided by investing activities		36,100
Cash flows from financing activities:
Distributions to partners	(2,131,000)	(4,975,700)
Net cash used in financing activities	(2,131,000)	$ (4,975,700)
Net change in cash	87,300
Cash at beginning of period	170,900
Cash at end of period	$ 258,200

Description of Business

Description of Business	9 Months Ended
	Sep. 30, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
DESCRIPTION OF BUSINESS	NOTE 1 - DESCRIPTION OF BUSINESS Atlas Resources Public #18-2009 (C) L.P. is a Delaware limited partnership, formed on June 9, 2009 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Titan Energy, LLC (“Titan”). Titan is an independent developer and producer of natural gas, crude oil, and natural gas liquids, with operations in basins across the United States. Titan is a leading sponsor and manager of tax-advantaged investment partnerships, in which it co-invests to finance a portion of its natural gas and oil production activities. Atlas Energy Group, LLC (“Atlas Energy Group”; OTC: ATLS) is a publicly traded company and operates Titan and the MGP through a 2% preferred member interest in Titan. The Partnership has drilled and currently operates wells located in Pennsylvania, Tennessee and Indiana. We have no employees and rely on our MGP for management, which in turn, relies on Atlas Energy Group for administrative services. The Partnership’s operating cash flows are generated from its wells, which produce natural gas. Produced natural gas is then delivered to market through affiliated and/or third-party gas gathering systems. The Partnership intends to produce its wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling. The condensed financial statements, which are unaudited, except for the balance sheet at December 31, 2015, which is derived from audited financial statements, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission and accounting principles generally accepted in the United States of America (“U.S. GAAP”) for interim reporting. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to those rules and regulations, although we believe that the disclosures made are adequate to make the information not misleading. These interim financial statements should be read in conjunction with the audited financial statements and notes thereto presented in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2015. The results of operations for the three and nine months ended September 30, 2016 may not necessarily be indicative of the results of operations for the year ended December 31, 2016. Atlas Resource Partners, L.P. Restructuring and Chapter 11 Bankruptcy Proceedings On July 25, 2016, Atlas Resource Partners, L.P. (“ARP”) and certain of its subsidiaries, including the MGP, and Atlas Energy Group, solely with respect to certain sections thereof, entered into a restructuring support agreement with ARP’s lenders (the “Restructuring Support Agreement”) to support ARP’s restructuring that reduced debt on its balance sheet (the “Restructuring”) pursuant to a pre-packaged plan of reorganization (the “Plan”). On July 27, 2016, ARP and certain of its subsidiaries, including the MGP, filed voluntary petitions for relief under Chapter 11 of the United States Bankruptcy Code (“Chapter 11”) in the United States Bankruptcy Court for the Southern District of New York (the “Bankruptcy Court”). The cases commenced thereby were being jointly administered under the caption “In re: ATLAS RESOURCE PARTNERS, L.P., et al.” ARP and the MGP operated the Partnership’s businesses as “debtors in possession” under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of Chapter 11 and the orders of the Bankruptcy Court. Under the Plan, all suppliers, vendors, employees, royalty owners, trade partners and landlords were unimpaired and will be satisfied in full in the ordinary course of business, and the MGP’s existing trade contracts and terms were maintained. To assure ordinary course operations, ARP and the MGP obtained interim approval from the Bankruptcy Court on a variety of “first day” motions, including motions seeking authority to use cash collateral on a consensual basis, pay wages and benefits for individuals who provide services to the Partnership, and pay vendors, oil and gas obligations and other creditor claims in the ordinary course of business. The Partnership was not a party to the Restructuring Support Agreement. The ARP Restructuring did not materially impact the MGP or its ability to perform as the managing general partner and operator of the Partnership’s operations. In June 2016, the MGP transferred $676,700 of funds to the Partnership based on projected monthly distributions to its limited partners over the next several months to ensure accessible distribution funding coverage in accordance with the Partnership’s operations and partnership agreements in the event the MGP experienced a prolonged restructuring period as the MGP performs all administrative and management functions for the Partnership. As of September 30, 2016, the Partnership has used these funds for distributions. On July 26, 2016, the MGP adopted certain amendments to our partnership agreement, in accordance with the MGP’s ability to amend our partnership agreement to cure an ambiguity in or correct or supplement any provision of our partnership agreement as may be inconsistent with any other provision, to provide that bankruptcy and insolvency events, such as the MGP’s Chapter 11 filing, with respect to the managing general partner would not cause the managing general partner to cease to serve as the managing general partner of the Partnership nor cause the termination of the Partnership. Atlas Energy Group was not a party to the ARP Restructuring. Atlas Energy Group remains controlled by the same ownership group and management team and thus, the ARP Restructuring did not have a material impact on the ability of Atlas Energy Group management to operate ARP or the other Atlas Energy Group businesses. On August 26, 2016, an order confirming ARP’s Plan was entered by the Bankruptcy Court. On September 1, 2016, ARP’s Plan became effective and ARP emerged as Titan. Liquidity, Capital Resources and Ability to Continue as a Going Concern The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on the Partnership’s liquidity position. In addition, the Partnership has experienced significant downward revisions of its natural gas and oil reserves volumes and values due to the declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be strategic in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the liquidation of the Partnership’s operations. Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, these conditions may raise substantial doubt about the Partnership’s ability to continue as a going concern. If the Partnership is not able to continue as a going concern, the Partnership will liquidate. If the Partnership’s operations are liquidated, a valuation of the Partnership’s assets and liabilities would be determined by an independent expert in accordance with the partnership agreement. It is possible that based on such determination, the Partnership would not be able to make any liquidation distributions to its limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners. The significant risks and uncertainties related to the Partnership’s ability to fund its operations may raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments to the carrying values and classification of the Partnership’s assets and liabilities and the reported amounts of income and expenses could be required and could be material. Liquidity and Capital Resources of the MGP The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under its credit facilities. The MGP’s primary cash requirements are operating expenses, debt service including interest, and capital expenditures. The MGP has historically funded its operations, acquisitions and cash distributions primarily through cash generated from operations, amounts available under its credit facilities and equity and debt offerings. The MGP’s future cash flows are subject to a number of variables, including oil and natural gas prices. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the MGP’s revenues, earnings and cash flows. Sustained low commodity prices could have a material and adverse effect on the MGP’s liquidity position. In addition, challenges with the MGP’s ability to raise capital through its drilling partnership program, either as a result of downturn in commodity prices or other difficulties affecting the fundraising channel, could negatively impact the MGP’s ability to remain in compliance with the covenants under its credit facilities. If the MGP is unable to remain in compliance with the covenants under its credit facilities, absent relief from its lenders, as applicable, the MGP may be forced to repay or refinance such indebtedness. Upon the occurrence of an event of default, the lenders under the MGP’s credit facilities, as applicable, could elect to declare all amounts outstanding immediately due and payable and the lenders could terminate all commitments to extend further credit. If an event of default occurs (including if the MGPs’s borrowing base is redetermined below its current outstanding borrowings and they are unable to repay the deficiency or deposit additional collateral to eliminate such deficiency), or if other debt agreements cross-default, and the lenders under the affected debt agreements accelerate the maturity of any loans or other debt outstanding, the MGP will not have sufficient liquidity to repay all of its outstanding indebtedness, and as a result, there would be substantial doubt regarding the MGP’s ability to continue as a going concern. The MGP continually monitors the capital markets and our capital structure and may make changes to its capital structure from time to time, with the goal of maintaining financial flexibility, preserving or improving liquidity, strengthening its balance sheet, meeting its debt service obligations and/or achieving cost efficiency. For example, the MGP could pursue options such as refinancing, restructuring or reorganizing its indebtedness or capital structure or seek to raise additional capital through debt or equity financing to address its liquidity concerns and high debt levels. The MGP also continues to implement various cost saving measures to reduce its capital, operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing its cost structure and, in turn, its liquidity to meet its capital and operating needs. The MGP cannot provide any assurances that any of these efforts will be successful or will result in cost reductions or cash flows or the timing of any such cost reductions or additional cash flows. It is also possible additional adjustments to the MGP’s plan and outlook may occur based on market conditions and its needs at that time, which could include selling assets, seeking additional partners to develop its assets, and/or reducing its planned capital program. In addition, to the extent commodity prices remain low or decline further, or the MGP experiences disruptions in its longer-term access to or cost of capital, the MGP’s ability to fund future capital expenditures, growth projects or the Partnership’s operations may be further impacted.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments, fair value of derivative instruments and the probability of forecasted transactions. The natural gas industry principally conducts its business by processing actual transactions as many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices . Gas and Oil Properties The following is a summary of gas and oil properties at the dates indicated: September 30, December 31, Proved properties: Leasehold interests $ 2,739,900 $ 2,739,900 Wells and related equipment 242,161,100 242,161,100 Total natural gas and oil properties 244,901,000 244,901,000 Accumulated depletion and impairment (211,541,600 ) (209,540,400 ) Gas and oil properties, net $ 33,359,400 $ 35,360,600 Recently Issued Accounting Standards In February 2016, the FASB updated the accounting guidance related to leases. The updated accounting guidance requires lessees to recognize a lease asset and liability at the commencement date of all leases (with the exception of short-term leases), initially measured at the present value of the lease payments. The updated guidance is effective for the Partnership as of January 1, 2019 and requires a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest period presented. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its financial statements. In August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its condensed financial statements. In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its condensed financial statements and its method of adoption.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
DERIVATIVE INSTRUMENTS	NOTE 3 - DERIVATIVE INSTRUMENTS The MGP, on behalf of the Partnership, uses a number of different derivative instruments, principally put contracts, in connection with the partnership’s commodity price risk management activities. The Partnership does not apply hedge accounting to any of its derivative instruments. As a result, gains and losses associated with derivative instruments are recognized in earnings. The Partnership enters into commodity put contracts to achieve more predictable cash flows by hedging the Partnership’s exposure to changes in commodity prices. At any point in time, such contracts may include regulated New York Mercantile Stock Exchange (“NYMEX”) futures and options contracts and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, but may be settled by the physical delivery of the commodity. These contracts have been recorded at their fair values. The Partnership reflected net derivative assets on its condensed balance sheets of $108,700 and $1,012,600 at September 30, 2016 and December 31, 2015, respectively. The following table summarizes the commodity derivative activity and presentation in the condensed statements of operations for the periods indicated: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Gain (loss) reclassified from accumulated other comprehensive income into natural gas and liquids revenues $ 200 $ (49,400 ) $ 500 $ (147,300 ) Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ 14,900 $ 369,300 $ 21,700 $ 593,900 At September 30, 2016, the Partnership had the following commodity derivatives: Natural Gas Fixed Price Swaps - Limited Partners Production Volumes (3) Average Fair Value (2) (MMBtu) (1) (per MMBtu) (1) 2016 75,100 $ 4.46 $ 108,700 (1) “MMBtu” represents million British Thermal Units (2) Fair value based on forward NYMEX natural gas prices, as applicable. (3) The production volume for 2016 include the remaining nine months of 2016 beginning October 1, 2016. At September 30, 2016, the MGP had a secured hedge facility agreement with a syndicate of banks under which the Partnership has the ability to enter into derivative contracts to manage its exposure to commodity price movements. Under the MGP’s revolving credit facility, the Partnership is required to utilize this secured hedge facility for future commodity risk management activity. The Partnership’s obligations under the facility are secured by mortgages on its gas and oil properties and first priority security interests in substantially all of its assets and are guaranteed by the MGP. The MGP administers the commodity price risk management activity for the Partnership under the secured hedge facility. The secured hedge facility agreement contains covenants that limit the Partnership’s ability to incur indebtedness, grant liens, make loans or investments, make distributions if a default under the secured hedge facility agreement exists or would result from the distribution, merge into or consolidate with other persons, enter into commodity or interest rate swap agreements that do not conform to specified terms or that exceed specified amounts, or engage in certain asset dispositions, including a sale of all or substantially all of its assets. As of September 30, 2016 only the Partnership’s natural gas swaps are included in the secured hedge facility. An event of default occurred under the secured hedging facility agreement upon the MGP’s filing of voluntary petitions for relief under Chapter 11. The lenders under the secured hedge facility agreed to forbear from exercising remedies in respect of such event of default while the Chapter 11 filings were pending and, upon occurrence of the effective date of the Plan contemplated by the Restructuring Support Agreement, such event of default was no longer be deemed to exist or to continue under the secured hedge facility. In addition, it will be an event of default under the MGP’s revolving credit facility if the MGP breaches an obligation governed by the secured hedge facility, and the effect of such breach is to cause amounts owing under swap agreements governed by the secured hedge facility to become immediately due and payable. Pursuant to the Restructuring Support Agreement, ARP completed the sale of substantially all of its commodity hedge positions on July 25, 2016 and July 26, 2016, which included the put contracts allocated to the Partnership. As of September 30, 2016, the value allocated to the Partnership is $35,000, net of put premiums of $88,800, which is recorded in accounts receivable trade – affiliate. The put contract value, net of the put premiums, was distributed to the partnership in October 2016.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
FAIR VALUE OF FINANCIAL INSTRUMENTS	NOTE 4 - FAIR VALUE OF FINANCIAL INSTRUMENTS The partnership uses a market approach fair value methodology to value the assets and liabilities for its outstanding derivative contracts Information for assets measured at fair value at September 30, 2016 and December 31, 2015 is as follows: Level 1 Level 2 Level 3 Total As of September 30, 2016 Derivative assets, gross Commodity swaps $ - $ 108,700 $ - $ 108,700 Commodity puts - - - - Total derivative assets, gross $ - $ 108,700 $ - $ 108,700 Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity swaps $ - $ 584,600 $ - $ 584,600 Commodity puts - 428,000 - 428,000 Total derivative assets, gross $ - $ 1,012,600 $ - $ 1,012,600

Certain Relationships and Relat

Certain Relationships and Related Party Transactions	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS	NOTE 5 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS The Partnership has entered into the following significant transactions with the MGP and its affiliates as provided under its Partnership Agreement. Administrative costs, which are included in general and administrative expenses in the Partnership’s condensed statements of operations, are payable at $75 per well per month. Monthly well supervision fees, which are included in production expenses in the Partnership’s condensed statements of operations, are payable at $975 per well per month for Marcellus wells, $1,500 per well per month for New Albany wells, and for all other wells a fee of $392 is charged per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s condensed statements of operations and are generally payable at 16% of the natural gas sales price. Direct costs, which are included in production and general administrative expenses in the Partnership’s condensed statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf. The following table provides information with respect to these costs and the periods incurred: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Administrative fees $ 16,100 $ 17,800 $ 48,600 $ 53,600 Supervision fees 221,600 251,600 673,500 763,600 Transportation fees 177,500 197,500 538,000 769,600 Direct costs 302,100 507,300 1,036,700 1,541,300 Total $ 717,300 $ 974,200 $ 2,296,800 $ 3,128,100 The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts receivable trade-affiliate on the Partnership’s condensed balance sheets includes the net production revenues due from the MGP. Subordination by Managing General Partner Under the terms of the Partnership Agreement, the MGP may be required up to 50% of its share of net production revenues so that the limited partners receive a return of at least 10% of their net subscriptions, determined on a cumulative basis, in each of the first five years of Partnership operations, commencing with the first distribution to the limited partners (August 2010). The subordination period expired in August 2015.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2016
Commitments And Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 6 - COMMITMENTS AND CONTINGENCIES General Commitments Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation. Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of September 30, 2016, the MGP withheld $196,900 of net production revenue for future plugging and abandonment costs. Legal Proceedings The Partnership and affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising out of the ordinary course of its business. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s or the MGP’s financial condition or results of operations.

Summary of Significant Accoun14

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2016
Summary Of Significant Accounting Policies [Line Items]
Liquidity, Capital Resources and Ability to Continue as a Going Concern	Liquidity, Capital Resources and Ability to Continue as a Going Concern The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on the Partnership’s liquidity position. In addition, the Partnership has experienced significant downward revisions of its natural gas and oil reserves volumes and values due to the declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be strategic in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the liquidation of the Partnership’s operations. Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, these conditions may raise substantial doubt about the Partnership’s ability to continue as a going concern. If the Partnership is not able to continue as a going concern, the Partnership will liquidate. If the Partnership’s operations are liquidated, a valuation of the Partnership’s assets and liabilities would be determined by an independent expert in accordance with the partnership agreement. It is possible that based on such determination, the Partnership would not be able to make any liquidation distributions to its limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners. The significant risks and uncertainties related to the Partnership’s ability to fund its operations may raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments to the carrying values and classification of the Partnership’s assets and liabilities and the reported amounts of income and expenses could be required and could be material. Liquidity and Capital Resources of the MGP The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under its credit facilities. The MGP’s primary cash requirements are operating expenses, debt service including interest, and capital expenditures. The MGP has historically funded its operations, acquisitions and cash distributions primarily through cash generated from operations, amounts available under its credit facilities and equity and debt offerings. The MGP’s future cash flows are subject to a number of variables, including oil and natural gas prices. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the MGP’s revenues, earnings and cash flows. Sustained low commodity prices could have a material and adverse effect on the MGP’s liquidity position. In addition, challenges with the MGP’s ability to raise capital through its drilling partnership program, either as a result of downturn in commodity prices or other difficulties affecting the fundraising channel, could negatively impact the MGP’s ability to remain in compliance with the covenants under its credit facilities. If the MGP is unable to remain in compliance with the covenants under its credit facilities, absent relief from its lenders, as applicable, the MGP may be forced to repay or refinance such indebtedness. Upon the occurrence of an event of default, the lenders under the MGP’s credit facilities, as applicable, could elect to declare all amounts outstanding immediately due and payable and the lenders could terminate all commitments to extend further credit. If an event of default occurs (including if the MGPs’s borrowing base is redetermined below its current outstanding borrowings and they are unable to repay the deficiency or deposit additional collateral to eliminate such deficiency), or if other debt agreements cross-default, and the lenders under the affected debt agreements accelerate the maturity of any loans or other debt outstanding, the MGP will not have sufficient liquidity to repay all of its outstanding indebtedness, and as a result, there would be substantial doubt regarding the MGP’s ability to continue as a going concern. The MGP continually monitors the capital markets and our capital structure and may make changes to its capital structure from time to time, with the goal of maintaining financial flexibility, preserving or improving liquidity, strengthening its balance sheet, meeting its debt service obligations and/or achieving cost efficiency. For example, the MGP could pursue options such as refinancing, restructuring or reorganizing its indebtedness or capital structure or seek to raise additional capital through debt or equity financing to address its liquidity concerns and high debt levels. The MGP also continues to implement various cost saving measures to reduce its capital, operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing its cost structure and, in turn, its liquidity to meet its capital and operating needs. The MGP cannot provide any assurances that any of these efforts will be successful or will result in cost reductions or cash flows or the timing of any such cost reductions or additional cash flows. It is also possible additional adjustments to the MGP’s plan and outlook may occur based on market conditions and its needs at that time, which could include selling assets, seeking additional partners to develop its assets, and/or reducing its planned capital program. In addition, to the extent commodity prices remain low or decline further, or the MGP experiences disruptions in its longer-term access to or cost of capital, the MGP’s ability to fund future capital expenditures, growth projects or the Partnership’s operations may be further impacted.
Use of Estimates	Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities that exist at the date of the Partnership’s condensed financial statements, as well as the reported amounts of revenues and costs and expenses during the reporting periods. The Partnership’s condensed financial statements are based on a number of significant estimates, including the revenue and expense accruals, depletion, impairments, fair value of derivative instruments and the probability of forecasted transactions. The natural gas industry principally conducts its business by processing actual transactions as many as 60 days after the month of delivery. Consequently, the most recent two months’ financial results were recorded using estimated volumes and contract market prices .
Gas and Oil Properties	Gas and Oil Properties The following is a summary of gas and oil properties at the dates indicated: September 30, December 31, Proved properties: Leasehold interests $ 2,739,900 $ 2,739,900 Wells and related equipment 242,161,100 242,161,100 Total natural gas and oil properties 244,901,000 244,901,000 Accumulated depletion and impairment (211,541,600 ) (209,540,400 ) Gas and oil properties, net $ 33,359,400 $ 35,360,600
Recently Issued Accounting Standards	Recently Issued Accounting Standards In February 2016, the FASB updated the accounting guidance related to leases. The updated accounting guidance requires lessees to recognize a lease asset and liability at the commencement date of all leases (with the exception of short-term leases), initially measured at the present value of the lease payments. The updated guidance is effective for the Partnership as of January 1, 2019 and requires a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest period presented. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its financial statements. In August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its condensed financial statements. In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its condensed financial statements and its method of adoption.
MGP
Summary Of Significant Accounting Policies [Line Items]
Liquidity and Capital Resources	Liquidity, Capital Resources and Ability to Continue as a Going Concern The Partnership is generally limited to the amount of funds generated by the cash flow from its operations to fund its obligations and make distributions, if any, to its partners. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on the Partnership’s liquidity position. In addition, the Partnership has experienced significant downward revisions of its natural gas and oil reserves volumes and values due to the declines in commodity prices. The MGP continues to implement various cost saving measures to reduce the Partnership’s operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be strategic in managing the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices remain low or decline further, or the Partnership experiences other disruptions in the industry, the Partnership’s ability to fund its operations and make distributions may be further impacted, and could result in the liquidation of the Partnership’s operations. Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from the Partnership’s operations have been adequate to fund its obligations and distributions to its partners. However, the recent significant declines in commodity prices have challenged the Partnership’s ability to fund its operations and may make it uneconomical for the Partnership to produce its wells until they are depleted as the Partnership originally intended. Accordingly, these conditions may raise substantial doubt about the Partnership’s ability to continue as a going concern. If the Partnership is not able to continue as a going concern, the Partnership will liquidate. If the Partnership’s operations are liquidated, a valuation of the Partnership’s assets and liabilities would be determined by an independent expert in accordance with the partnership agreement. It is possible that based on such determination, the Partnership would not be able to make any liquidation distributions to its limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners. The significant risks and uncertainties related to the Partnership’s ability to fund its operations may raise substantial doubt about the Partnership’s ability to continue as a going concern. The financial statements have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The financial statements do not include any adjustments that might result from the outcome of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments to the carrying values and classification of the Partnership’s assets and liabilities and the reported amounts of income and expenses could be required and could be material. Liquidity and Capital Resources of the MGP The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under its credit facilities. The MGP’s primary cash requirements are operating expenses, debt service including interest, and capital expenditures. The MGP has historically funded its operations, acquisitions and cash distributions primarily through cash generated from operations, amounts available under its credit facilities and equity and debt offerings. The MGP’s future cash flows are subject to a number of variables, including oil and natural gas prices. Prices for oil and natural gas began to decline significantly during the fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted the MGP’s revenues, earnings and cash flows. Sustained low commodity prices could have a material and adverse effect on the MGP’s liquidity position. In addition, challenges with the MGP’s ability to raise capital through its drilling partnership program, either as a result of downturn in commodity prices or other difficulties affecting the fundraising channel, could negatively impact the MGP’s ability to remain in compliance with the covenants under its credit facilities. If the MGP is unable to remain in compliance with the covenants under its credit facilities, absent relief from its lenders, as applicable, the MGP may be forced to repay or refinance such indebtedness. Upon the occurrence of an event of default, the lenders under the MGP’s credit facilities, as applicable, could elect to declare all amounts outstanding immediately due and payable and the lenders could terminate all commitments to extend further credit. If an event of default occurs (including if the MGPs’s borrowing base is redetermined below its current outstanding borrowings and they are unable to repay the deficiency or deposit additional collateral to eliminate such deficiency), or if other debt agreements cross-default, and the lenders under the affected debt agreements accelerate the maturity of any loans or other debt outstanding, the MGP will not have sufficient liquidity to repay all of its outstanding indebtedness, and as a result, there would be substantial doubt regarding the MGP’s ability to continue as a going concern. The MGP continually monitors the capital markets and our capital structure and may make changes to its capital structure from time to time, with the goal of maintaining financial flexibility, preserving or improving liquidity, strengthening its balance sheet, meeting its debt service obligations and/or achieving cost efficiency. For example, the MGP could pursue options such as refinancing, restructuring or reorganizing its indebtedness or capital structure or seek to raise additional capital through debt or equity financing to address its liquidity concerns and high debt levels. The MGP also continues to implement various cost saving measures to reduce its capital, operating and general and administrative costs, including renegotiating contracts with contractors, suppliers and service providers, reducing the number of staff and contractors and deferring and eliminating discretionary costs. The MGP will continue to be opportunistic and aggressive in managing its cost structure and, in turn, its liquidity to meet its capital and operating needs. The MGP cannot provide any assurances that any of these efforts will be successful or will result in cost reductions or cash flows or the timing of any such cost reductions or additional cash flows. It is also possible additional adjustments to the MGP’s plan and outlook may occur based on market conditions and its needs at that time, which could include selling assets, seeking additional partners to develop its assets, and/or reducing its planned capital program. In addition, to the extent commodity prices remain low or decline further, or the MGP experiences disruptions in its longer-term access to or cost of capital, the MGP’s ability to fund future capital expenditures, growth projects or the Partnership’s operations may be further impacted.

Summary of Significant Accoun15

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Summary of Gas and Oil Properties	The following is a summary of gas and oil properties at the dates indicated: September 30, December 31, Proved properties: Leasehold interests $ 2,739,900 $ 2,739,900 Wells and related equipment 242,161,100 242,161,100 Total natural gas and oil properties 244,901,000 244,901,000 Accumulated depletion and impairment (211,541,600 ) (209,540,400 ) Gas and oil properties, net $ 33,359,400 $ 35,360,600

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Summary of Commodity Derivative Activity and Presentation in Condensed Statements of Operations	The following table summarizes the commodity derivative activity and presentation in the condensed statements of operations for the periods indicated: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Gain (loss) reclassified from accumulated other comprehensive income into natural gas and liquids revenues $ 200 $ (49,400 ) $ 500 $ (147,300 ) Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ 14,900 $ 369,300 $ 21,700 $ 593,900
Commodity Derivatives	At September 30, 2016, the Partnership had the following commodity derivatives: Natural Gas Fixed Price Swaps - Limited Partners Production Volumes (3) Average Fair Value (2) (MMBtu) (1) (per MMBtu) (1) 2016 75,100 $ 4.46 $ 108,700 (1) “MMBtu” represents million British Thermal Units (2) Fair value based on forward NYMEX natural gas prices, as applicable. (3) The production volume for 2016 include the remaining nine months of 2016 beginning October 1, 2016.

Fair Value of Financial Instr17

Fair Value of Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Assets Measured at Fair Value on a Recurring Basis	Information for assets measured at fair value at September 30, 2016 and December 31, 2015 is as follows: Level 1 Level 2 Level 3 Total As of September 30, 2016 Derivative assets, gross Commodity swaps $ - $ 108,700 $ - $ 108,700 Commodity puts - - - - Total derivative assets, gross $ - $ 108,700 $ - $ 108,700 Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity swaps $ - $ 584,600 $ - $ 584,600 Commodity puts - 428,000 - 428,000 Total derivative assets, gross $ - $ 1,012,600 $ - $ 1,012,600

Certain Relationships and Rel18

Certain Relationships and Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Certain Relationships and Related Party Transactions	The following table provides information with respect to these costs and the periods incurred: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Administrative fees $ 16,100 $ 17,800 $ 48,600 $ 53,600 Supervision fees 221,600 251,600 673,500 763,600 Transportation fees 177,500 197,500 538,000 769,600 Direct costs 302,100 507,300 1,036,700 1,541,300 Total $ 717,300 $ 974,200 $ 2,296,800 $ 3,128,100

Description of Business (Detail

Description of Business (Details) - USD ($)	9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016
Description Of Business [Line Items]
Atlas Resources Public #18-2009 (C) L.P.	Jun. 9, 2009
MGP
Description Of Business [Line Items]
Funds transferred to partners		$ 676,700
Atlas Energy Group, LLC | Titan Energy, LLC | Preferred Member Interest
Description Of Business [Line Items]
Percentage of preferred interest	2.00%

Summary of Significant Accoun20

Summary of Significant Accounting Policies (Summary of Gas and Oil Properties) (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 244,901,000	$ 244,901,000
Accumulated depletion and impairment	(211,541,600)	(209,540,400)
Gas and oil properties, net	33,359,400	35,360,600
Leasehold interests
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	2,739,900	2,739,900
Wells and related equipment
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 242,161,100	$ 242,161,100

Derivative Instruments (Narrati

Derivative Instruments (Narrative) (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Derivative [Line Items]
Net derivative assets	$ 108,700	$ 1,012,600
ARP | Commodity Hedge | Put Contracts | Accounts Receivable Trade –Affiliate
Derivative [Line Items]
Value allocated to partnership	35,000
Put premium value	$ 88,800

Derivative Instruments (Summary

Derivative Instruments (Summary of Commodity Derivative Activity and Presentation in Condensed Statements of Operations) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Gain (loss) reclassified from accumulated other comprehensive income into natural gas and liquids revenues	$ 200	$ (49,400)	$ 500	$ (147,300)
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$ 14,900	$ 369,300	$ 21,700	$ 593,900

Derivative Instruments (Commodi

Derivative Instruments (Commodity Derivatives) (Details)		9 Months Ended
		Sep. 30, 2016USD ($)MMBTU$ / MMBTU	Dec. 31, 2015USD ($)
Derivative [Line Items]
Fair Value Asset		$ 108,700	$ 1,012,600
Designated as Hedging Instrument | Natural Gas Fixed Price Swaps Production Period December 31, 2016
Derivative [Line Items]
Volumes | MMBTU	[1],[2]	75,100
Average Fixed Price (per MMBtu) | $ / MMBTU	[2]	4.46
Fair Value Asset	[3]	$ 108,700
[1]	The production volume for 2016 include the remaining nine months of 2016 beginning October 1, 2016.
[2]	“MMBtu” represents million British Thermal Units
[3]	Fair value based on forward NYMEX natural gas prices, as applicable.

Fair Value of Financial Instr24

Fair Value of Financial Instruments (Assets Measured at Fair Value on a Recurring Basis) (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 108,700	$ 1,012,600
Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	108,700	1,012,600
Commodity Swaps
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	108,700	584,600
Commodity Swaps | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 108,700	584,600
Commodity Puts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset		428,000
Commodity Puts | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset		$ 428,000

Certain Relationships and Rel25

Certain Relationships and Related Party Transactions (Narrative) (Details)	9 Months Ended
	Sep. 30, 2016$ / mo
Related Party Transaction [Line Items]
Managing General Partner Maximum Subordination Percentage Of Share Of Net Production Revenues	50.00%
MGP
Related Party Transaction [Line Items]
Subordination Target Return Rate For Limited Partner Subscriptions	10.00%
MGP and Affiliates | General and administrative expenses
Related Party Transaction [Line Items]
Monthly Administrative Costs Per Well	75
MGP and Affiliates | Production
Related Party Transaction [Line Items]
Transportation Fee Rate As Percentage Of Natural Gas Sales Price	16.00%
MGP and Affiliates | Production | Marcellus wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	975
MGP and Affiliates | Production | New Albany Wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	1,500
MGP and Affiliates | Production | Other Wells
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	392

Certain Relationships and Rel26

Certain Relationships and Related Party Transactions (Certain Relationships and Related Party Transactions) (Details) - MGP and Affiliates - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 717,300	$ 974,200	$ 2,296,800	$ 3,128,100
Administrative fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	16,100	17,800	48,600	53,600
Supervision fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	221,600	251,600	673,500	763,600
Transportation fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	177,500	197,500	538,000	769,600
Direct costs
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 302,100	$ 507,300	$ 1,036,700	$ 1,541,300

Commitments and Contingencies (

Commitments and Contingencies (Narrative) (Details)	9 Months Ended
	Sep. 30, 2016USD ($)$ / mo
Commitments And Contingencies Disclosure [Abstract]
Investor Partners Ownership Interest Presented For Purchase By The MGP, Maximum Percentage	5.00%
Operator Fee Per Well To Cover Estimated Future Plugging And Abandonment Costs, Monthly | $ / mo	200
Net production revenue for future plugging and abandonment costs | $	$ 196,900