ATLAS AMERICA Public #9 10-Q 15 May 18 2018 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	3 Months Ended
	Mar. 31, 2018shares
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1
Entity Registrant Name	ATLAS AMERICA Public #9 LTD.
Entity Central Index Key	1,121,745
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 ($)	Mar. 31, 2018	Dec. 31, 2017
Current assets:
Cash	$ 0	$ 0
Accounts receivable trade-affiliate	39,200	35,500
Total current assets	39,200	35,500
Gas and oil properties, net	65,500	65,500
Long-term asset retirement receivable-affiliate	621,800	576,900
Total assets	726,500	677,900
Current liabilities:
Accounts payable trade-affiliate	1,167,200	1,080,300
Accrued liabilities	6,100	9,900
Total current liabilities	1,173,300	1,090,200
Asset retirement obligations	1,918,200	1,900,900
Commitments and contingencies (Note 4)
Partners’ deficit:
Managing general partner’s deficit	(816,300)	(798,100)
Limited partners’ deficit (1,500 units)	(1,548,700)	(1,515,100)
Total partners’ deficit	(2,365,000)	(2,313,200)
Total liabilities and partners’ deficit	$ 726,500	$ 677,900

CONDENSED BALANCE SHEETS (Paren

CONDENSED BALANCE SHEETS (Parenthetical) - shares	Mar. 31, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Limited partners' units	1,500	1,500

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS - USD ($)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
REVENUES
Natural gas and oil	$ 78,500	$ 86,600
Total revenues	78,500	86,600
COSTS AND EXPENSES
Production	76,400	80,600
Accretion of asset retirement obligations	17,300	17,700
General and administrative	36,600	28,400
Total costs and expenses	130,300	126,700
Net loss	(51,800)	(40,100)
Allocation of net loss:
Managing general partner	(18,200)	(14,300)
Limited partners	$ (33,600)	$ (25,800)
Net loss per limited partnership units (in dollars per share)	$ (22)	$ (17)

CONDENSED STATEMENT OF CHANGES

CONDENSED STATEMENT OF CHANGES IN PARTNERS' DEFICIT - 3 months ended Mar. 31, 2018 - USD ($)	Total	Managing General Partner	Limited Partners
Beginning balance at Dec. 31, 2017	$ (2,313,200)	$ (798,100)	$ (1,515,100)
Participation in revenues, costs and expenses:
Net production expenses	2,100	800	1,300
Accretion of asset retirement obligations	(17,300)	(6,100)	(11,200)
General and administrative	(36,600)	(12,900)	(23,700)
Net loss	(51,800)	(18,200)	(33,600)
Ending balance at Mar. 31, 2018	$ (2,365,000)	$ (816,300)	$ (1,548,700)

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS - USD ($)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Cash flows used in operating activities:
Net loss	$ (51,800)	$ (40,100)
Adjustments to reconcile net loss to net cash provided by operating activities:
Accretion of asset retirement obligations	17,300	17,700
Changes in operating assets and liabilities:
Increase in accounts receivable trade-affiliate	(3,700)	(2,200)
Increase in asset retirement receivable-affiliate	(44,900)	(48,700)
Increase in accounts payable trade-affiliate	86,900	79,500
Decrease in accrued liabilities	(3,800)	(6,200)
Net cash provided by operating activities	0	0
Cash flows from investing activities:
Net cash provided by investing activities	0	0
Cash flows from financing activities:
Net cash used in financing activities	0	0
Net change in cash	0	0
Cash at beginning of period	0	0
Cash at end of period	$ 0	$ 0

Description of Business

Description of Business	3 Months Ended
	Mar. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
DESCRIPTION OF BUSINESS	DESCRIPTION OF BUSINESS Atlas America Public #9 LTD. (the “Partnership”) is a Pennsylvania limited partnership, formed on July 27, 2000 . DGOC Partnership Holdings, LLC serves as its Managing General Partner (“DGOC Holdings” or the “MGP”) and certain affiliates of the MGP serve as our Operators ("Operators"). DGOC Holdings is an indirect subsidiary of Diversified Gas & Oil, PLC (“Diversified”; AIM: DGOC). Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to Atlas America Public #9 LTD. The Partnership has drilled and currently operates wells located in Pennsylvania and Ohio. We have no employees and rely on our MGP to staff and manage our operations, which in turn, relied on Atlas Energy Group, LLC, Titan’s parent company, for administrative services through a Transition Services Agreement effective through December 31, 2017. Since the expiration of the TSA, staffing is provided by an affiliate of Diversified. The Partnership’s operating cash flows are generated from its wells, which produce natural gas and oil. Produced natural gas and oil is then delivered to market through third-party gas gathering systems. The Partnership intends to produce its wells until they are sold, depleted or become uneconomical to produce at which time they will be plugged and abandoned. The Partnership does not expect to drill additional wells and expects no additional funds will be required for drilling. The economic viability of the Partnership’s production is based on a variety of factors including proved developed producing reserves that it expects to recover using existing equipment and operating methods or proved reserves recoverable where the cost of the necessary additional extraction equipment is relatively minor compared to the cost of a new well and through currently installed extraction equipment and related infrastructure which is operational at the time of the reserves estimate (if the extraction is by means not involving drilling, completing or reworking a well). Numerous uncertainties are inherent in estimating quantities of proved reserves and in projecting future net revenues. The prices at which the Partnership’s natural gas and oil will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas and oil prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas and oil prices may, in addition to decreasing the Partnership’s revenues, also reduce the amount of natural gas that the Partnership can produce economically. 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 continue to remain low, on a relative basis, in 2018 . Lower commodity prices negatively impact the Partnership’s revenues, earnings and cash flows, and having persisted on a sustained basis have materially adversely effect the Partnership’s liquidity position, resulting in net operating losses since 2015. Additionally, in 2015 the Partnership 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 its strategic effort to manage the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices continue to 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. 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, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership's operations and to fund the Partnership's obligations for at least twelve months from the date the financial statements are issued. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership's ability to continue as a going concern.

Summary of Significant Accounti

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES These condensed financial statements are unaudited, but in the opinion of management, reflect all adjustments necessary for a fair presentation of results for the interim periods presented. All adjustments are of a normal recurring nature unless disclosed otherwise. Interim period results are not necessarily indicative of results to be expected for the full year. These condensed financial statements have been prepared in accordance with rules of the Securities and Exchange Commission (“SEC”) and do not include all the information and disclosures required by accounting principles generally accepted in the United States (“GAAP”) for complete financial statements. They should be read in conjunction with the financial statements for the year ended December 31, 2017 and notes thereto included in our 2017 Annual Report on Form 10-K, which include a summary of the significant accounting policies. Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires the MGP 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 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. Actual results could differ from those estimates. Gas and Oil Properties The following is a summary of natural gas and oil properties at the dates indicated: March 31, December 31, Change 2018 2017 $ % Proved properties: Leasehold interests $ 254,600 $ 254,600 $ — — Wells and related equipment 18,721,700 18,721,700 — — Total natural gas and oil properties 18,976,300 18,976,300 — — Accumulated depletion and impairment (18,910,800 ) (18,910,800 ) — — Gas and oil properties, net $ 65,500 $ 65,500 $ — — Sustained low commodity prices and the associated recorded impairment charges have driven the remaining net book value of gas and oil properties on our condensed balance sheets at March 31, 2018 and December 31, 2017 to be entirely related to the estimated salvage value of such properties. The estimated salvage values are based on the MGP’s historical experience in determining such values. Recently Adopted Accounting Standards In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The standard requires an entity to identify all customer contracts and their corresponding performance obligations, determine the transaction price and its allocation, at the entity level, and to recognize revenue upon fulfillment of the performance obligation. ASU 2014-09 replaces most of the existing revenue recognition requirements in GAAP. The Partnership adopted the standard on January 1, 2018 using the modified retrospective method as of the adoption date. The new standard did not have a material impact on the Partnership's Financial Statements other than requiring new disclosures. Revenue Recognition The Partnership sells natural gas under multiple purchaser contracts. The Partnership’s performance obligation, to the customer, includes the production and sale of natural gas at multiple delivery points. The sales contracts are based on blended rate pricing provisions with fixed and variable components. The fixed component is well defined, under each purchaser contract, and is tied to base production levels. The variable component is generally tied to a regional market index and is received for anything in excess of the base production levels outlined under each customer contract. Under certain agreements, the Partnership’s natural gas sales are delivered to midstream processing entities and DGOC Partnership Holdings, LLC is in control of the gas asset at all points of sale to the purchaser(s). The gathering fees charged, by the midstream processing agents, are paid at the gross rate, by the Partnership as production costs which is consistent with prior reporting periods. The Partnership recognizes revenue and related accounts receivable in the month the performance obligation has been met. However; the settlement statements may not be received from the purchaser for 30-90 days after the production is delivered. As a result, DGOC Partnership Holdings, LLC is required to estimate and accrue for the current month’s revenue using well defined processes that have historically demonstrated close proximities to actual payments. The current revenue accruals have existing internal controls and are evaluated, for accuracy, on a regular basis. Revenues from the production of natural gas, in which the Partnership has an interest with other producers, are recognized on the basis of its percentage ownership of working interest and/or overriding royalty. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses.

Certain Relationships and Relat

Certain Relationships and Related Party Transactions	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS	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 expense in the Partnership’s condensed statements of operations, are payable at $ 337 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 payable at either 16% of the natural gas sales price or $0.35 per Mcf, whichever is greater. 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. Direct costs that are in excess of earnings are recorded as an increase to accounts payable trade-affiliate and reflected as changes in operating assets and liabilities in the operating section of the Condensed Statement of Cash Flows. The following table provides information with respect to these costs and the periods incurred: Three Months Ended Change 2018 2017* $ % Administrative fees $ 12,800 $ 13,500 $ (700 ) (5 )% Supervision fees 57,800 60,600 (2,800 ) (5 )% Transportation fees 10,100 9,400 700 7 % Direct costs 32,300 25,500 6,800 27 % Total $ 113,000 $ 109,000 $ 4,000 4 % * Amounts paid to the Previous MGP. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts payable trade-affiliate on the Partnership’s balance sheets includes the net production expenses due to the MGP.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	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, our Operators may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2018 , the Operators have withheld $621,800 of net production revenue for future plugging and abandonment costs. Environmental risk is inherent to oil and natural gas operations, and we and our affiliates may be, at times, subject to potential environmental remediation liability. We manage this environmental risk through appropriate environmental policies and practices to minimize any impact our operations may have on the environment. To the extent that we are unable to recover payment for environmental liabilities from insurance or other potentially responsible parties, we will be responsible for payment of liabilities arising from environmental incidents associated with the operating activities of our oil and natural gas operations. 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 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 Accoun11

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
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 continue to remain low, on a relative basis, in 2018 . Lower commodity prices negatively impact the Partnership’s revenues, earnings and cash flows, and having persisted on a sustained basis have materially adversely effect the Partnership’s liquidity position, resulting in net operating losses since 2015. Additionally, in 2015 the Partnership 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 its strategic effort to manage the Partnership’s cost structure and, in turn, liquidity to meet its operating needs. To the extent commodity prices continue to 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. 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, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership's operations and to fund the Partnership's obligations for at least twelve months from the date the financial statements are issued. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership's ability to continue as a going concern.
Use of Estimates	Use of Estimates The preparation of the Partnership’s condensed financial statements in conformity with U.S. GAAP requires the MGP 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 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. Actual results could differ from those estimates.
Recently Issued Accounting Standards	Recently Adopted Accounting Standards In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The standard requires an entity to identify all customer contracts and their corresponding performance obligations, determine the transaction price and its allocation, at the entity level, and to recognize revenue upon fulfillment of the performance obligation. ASU 2014-09 replaces most of the existing revenue recognition requirements in GAAP. The Partnership adopted the standard on January 1, 2018 using the modified retrospective method as of the adoption date. The new standard did not have a material impact on the Partnership's Financial Statements other than requiring new disclosures.
Revenue Recognition	Revenue Recognition The Partnership sells natural gas under multiple purchaser contracts. The Partnership’s performance obligation, to the customer, includes the production and sale of natural gas at multiple delivery points. The sales contracts are based on blended rate pricing provisions with fixed and variable components. The fixed component is well defined, under each purchaser contract, and is tied to base production levels. The variable component is generally tied to a regional market index and is received for anything in excess of the base production levels outlined under each customer contract. Under certain agreements, the Partnership’s natural gas sales are delivered to midstream processing entities and DGOC Partnership Holdings, LLC is in control of the gas asset at all points of sale to the purchaser(s). The gathering fees charged, by the midstream processing agents, are paid at the gross rate, by the Partnership as production costs which is consistent with prior reporting periods. The Partnership recognizes revenue and related accounts receivable in the month the performance obligation has been met. However; the settlement statements may not be received from the purchaser for 30-90 days after the production is delivered. As a result, DGOC Partnership Holdings, LLC is required to estimate and accrue for the current month’s revenue using well defined processes that have historically demonstrated close proximities to actual payments. The current revenue accruals have existing internal controls and are evaluated, for accuracy, on a regular basis. Revenues from the production of natural gas, in which the Partnership has an interest with other producers, are recognized on the basis of its percentage ownership of working interest and/or overriding royalty. The MGP and its affiliates perform all administrative and management functions for the Partnership, including billing revenues and paying expenses.

Summary of Significant Accoun12

Summary of Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
Gas and Oil Properties	The following is a summary of natural gas and oil properties at the dates indicated: March 31, December 31, Change 2018 2017 $ % Proved properties: Leasehold interests $ 254,600 $ 254,600 $ — — Wells and related equipment 18,721,700 18,721,700 — — Total natural gas and oil properties 18,976,300 18,976,300 — — Accumulated depletion and impairment (18,910,800 ) (18,910,800 ) — — Gas and oil properties, net $ 65,500 $ 65,500 $ — —

Certain Relationships and Rel13

Certain Relationships and Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2018
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 Change 2018 2017* $ % Administrative fees $ 12,800 $ 13,500 $ (700 ) (5 )% Supervision fees 57,800 60,600 (2,800 ) (5 )% Transportation fees 10,100 9,400 700 7 % Direct costs 32,300 25,500 6,800 27 % Total $ 113,000 $ 109,000 $ 4,000 4 % * Amounts paid to the Previous MGP.

Summary of Significant Accoun14

Summary of Significant Accounting Policies - Gas and Oil Properties (Details) - USD ($)	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Natural gas and oil properties	$ 18,976,300	$ 18,976,300
Accumulated depletion and impairment	(18,910,800)	(18,910,800)
Gas and oil properties, net	65,500	65,500
Natural gas and oil properties, $ change	0
Accumulated depletion and amortization, $ change	0
Gas and oil properties, net, $ change	$ 0
Natural gas and oil properties, % change	0.00%
Accumulated depletion and impairment, % change	0.00%
Gas and oil properties, net, % change	0.00%
Leasehold interests
Property, Plant and Equipment [Line Items]
Natural gas and oil properties	$ 254,600	254,600
Natural gas and oil properties, $ change	$ 0
Natural gas and oil properties, % change	0.00%
Wells and related equipment
Property, Plant and Equipment [Line Items]
Natural gas and oil properties	$ 18,721,700	$ 18,721,700
Natural gas and oil properties, $ change	$ 0
Natural gas and oil properties, % change	0.00%

Certain Relationships and Rel15

Certain Relationships and Related Party Transactions (Details) - MGP and Affiliates	3 Months Ended
	Mar. 31, 2018USD ($)$ / mo
General and administrative expenses
Related Party Transaction [Line Items]
Monthly administrative costs per well	75
Production
Related Party Transaction [Line Items]
Monthly supervision fees per well	337
Transportation fee rate as percentage of natural gas sales price	16.00%
Transportation fees (USD per Mcf) | $	$ 0.35

Certain Relationships and Rel16

Certain Relationships and Related Party Transactions - Costs and the Periods Incurred (Details) - MGP and Affiliates - USD ($)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 113,000	$ 109,000
Related party transactions, $ change	$ 4,000
Related party transactions, % change	4.00%
Administrative fees
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 12,800	13,500
Related party transactions, $ change	$ (700)
Related party transactions, % change	(5.00%)
Supervision fees
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 57,800	60,600
Related party transactions, $ change	$ (2,800)
Related party transactions, % change	(5.00%)
Transportation fees
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 10,100	9,400
Related party transactions, $ change	$ 700
Related party transactions, % change	7.00%
Direct costs
Related Party Transaction [Line Items]
Related party transaction, expenses from transactions with related party	$ 32,300	$ 25,500
Related party transactions, $ change	$ 6,800
Related party transactions, % change	27.00%

Commitments and Contingencies (

Commitments and Contingencies (Details)	3 Months Ended
	Mar. 31, 2018USD ($)$ / mo	Dec. 31, 2017USD ($)
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
Long-term asset retirement receivable-affiliate | $	$ 621,800	$ 576,900