ATLAS AMERICA Public #9 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 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 (Unaud

CONDENSED BALANCE SHEETS (Unaudited) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash	$ 0	$ 0
Accounts receivable trade-affiliate	31,800	29,600
Current portion of derivative assets	0	13,400
Total current assets	31,800	43,000
Gas and oil properties, net	537,000	537,000
Long-term asset retirement receivable-affiliate	333,900	188,100
Total assets	902,700	768,100
Current liabilities:
Accounts payable trade-affiliate	624,500	302,300
Accrued liabilities	13,100	10,300
Put premiums payable-affiliate		6,200
Total current liabilities	637,600	318,800
Asset retirement obligations	1,931,100	1,879,800
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit	(264,300)	(181,000)
Limited partners’ deficit (1,500 units)	(1,401,700)	(1,250,200)
Accumulated other comprehensive income		700
Total partners’ deficit	(1,666,000)	(1,430,500)
Total liabilities and partners’ deficit	$ 902,700	$ 768,100

CONDENSED BALANCE SHEETS (Unau3

CONDENSED BALANCE SHEETS (Unaudited) (Parenthetical)	Sep. 30, 2016shares
Statement Of Financial Position [Abstract]
Limited partners' units	1,500

CONDENSED STATEMENTS OF OPERATI

CONDENSED STATEMENTS OF OPERATIONS (Unaudited) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
REVENUES
Natural gas and oil	$ 55,400	$ 47,000	$ 149,200	$ 203,200
Gain (loss) on mark-to-market derivatives		4,500	(100)	4,600
Total revenues	55,400	51,500	149,100	207,800
COSTS AND EXPENSES
Production	74,100	81,200	254,100	264,200
Depletion		8,400		27,600
Impairment		457,200		457,200
Accretion of asset retirement obligations	17,000	25,400	51,300	76,300
General and administrative	26,100	25,800	78,500	81,000
Total costs and expenses	117,200	598,000	383,900	906,300
Net loss	(61,800)	(546,500)	(234,800)	(698,500)
Allocation of net loss:
Managing general partner	(21,900)	(221,100)	(83,300)	(277,200)
Limited partners	$ (39,900)	$ (325,400)	$ (151,500)	$ (421,300)
Net loss per limited partnership unit	$ (27)	$ (217)	$ (101)	$ (281)

CONDENSED STATEMENTS OF COMPREH

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited) - 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	$ (61,800)	$ (546,500)	$ (234,800)	$ (698,500)
Other comprehensive loss:
Difference in estimated hedge gains receivable		(1,600)		200
Less: reclassification adjustment for realized (gain) loss of cash flow hedges in net loss	(300)	900	(700)	(2,200)
Total other comprehensive loss	(300)	(700)	(700)	(2,000)
Comprehensive loss	$ (62,100)	$ (547,200)	$ (235,500)	$ (700,500)

CONDENSED STATEMENT OF CHANGES

CONDENSED STATEMENT OF CHANGES IN PARTNERS' DEFICIT (Unaudited) - 9 months ended Sep. 30, 2016 - USD ($)	Total	Managing General Partner	Limited Partners	Accumulated Other Comprehensive Income
Beginning balance at Dec. 31, 2015	$ (1,430,500)	$ (181,000)	$ (1,250,200)	$ 700
Participation in revenues, costs and expenses:
Net production expenses	(104,900)	(37,200)	(67,700)
Loss on mark-to-market derivatives	(100)		(100)
Accretion of asset retirement obligations	(51,300)	(18,200)	(33,100)
General and administrative	(78,500)	(27,900)	(50,600)
Net loss	(234,800)	(83,300)	(151,500)
Other comprehensive loss	(700)			$ (700)
Ending balance at Sep. 30, 2016	$ (1,666,000)	$ (264,300)	$ (1,401,700)

CONDENSED STATEMENTS OF CASH FL

CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows used in operating activities:
Net loss	$ (234,800)	$ (698,500)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion		27,600
Impairment		457,200
Non-cash loss (gain) on derivative value	6,500	(4,000)
Accretion of asset retirement obligations	51,300	76,300
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable trade-affiliate	(2,200)	65,500
Increase in asset retirement receivable-affiliate	(145,800)	(129,600)
Increase in accounts payable trade-affiliate	322,200	202,000
Increase in accrued liabilities	2,800	3,300
Net cash used in operating activities		(200)
Cash flows from investing activities:
Net cash provided by investing activities		200
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	9 Months Ended
	Sep. 30, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
DESCRIPTION OF BUSINESS	NOTE 1 - DESCRIPTION OF BUSINESS Atlas America Public #9 LTD. (the “Partnership”) is a Pennsylvania limited partnership, formed on July 27, 2000 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 and Ohio. We have no employees and rely on our MGP for management, which in turn, relies on Atlas Energy Group for administrative services. (See Item 11: “Executive Compensation”). 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 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. The economic viability of the Partnership’s production is based on a variety of factors including proved developed reserves that it can expect to recover through existing wells with existing equipment and operating methods or in which the cost of additional required 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). There are numerous uncertainties inherent in estimating quantities of proven 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 not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas and oil that the Partnership can produce economically. 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. 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 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 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 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. Actual results could differ from those estimates. 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 $ 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 (18,439,300 ) (18,439,300 ) Gas and oil properties, net $ 537,000 $ 537,000 As a result of the recent significant declines in commodity prices and associated recorded impairment charges, remaining net book value of gas and oil properties on our condensed 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 $0 and $13,400 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 oil revenues $ 300 $ (900) $ 700 $ 2,200 Gain (loss) subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ - $ 4,500 $ (100 ) $ 4,600 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 $1,000, net of put premiums of $2,500, 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 for its outstanding derivative contracts Information for assets measured at fair value at September 30, 2016 and December 31, 2015 was as follows: Level 1 Level 2 Level 3 Total As of September 30, 2016 Derivative assets, gross Commodity puts $ - $ - $ - $ - Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity puts $ - $ 13,400 $ - $ 13,400

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 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 generally payable at 13% 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 $ 12,300 $ 11,700 $ 37,000 $ 39,000 Supervision fees 55,200 52,500 166,400 175,500 Transportation fees 6,800 6,200 18,700 23,700 Direct costs 25,900 36,600 110,500 107,000 Total $ 100,200 $ 107,000 $ 332,600 $ 345,200 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 condensed balance sheets includes the net production expenses due to the MGP.

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 has withheld $333,900 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 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 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 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.
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. Actual results could differ from those estimates.
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 $ 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 (18,439,300 ) (18,439,300 ) Gas and oil properties, net $ 537,000 $ 537,000 As a result of the recent significant declines in commodity prices and associated recorded impairment charges, remaining net book value of gas and oil properties on our condensed
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 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 $ 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 (18,439,300 ) (18,439,300 ) Gas and oil properties, net $ 537,000 $ 537,000

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 the 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 oil revenues $ 300 $ (900) $ 700 $ 2,200 Gain (loss) subsequent to hedge accounting recognized in gain on mark-to-market derivatives $ - $ 4,500 $ (100 ) $ 4,600

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 was as follows: Level 1 Level 2 Level 3 Total As of September 30, 2016 Derivative assets, gross Commodity puts $ - $ - $ - $ - Level 1 Level 2 Level 3 Total As of December 31, 2015 Derivative assets, gross Commodity puts $ - $ 13,400 $ - $ 13,400

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 $ 12,300 $ 11,700 $ 37,000 $ 39,000 Supervision fees 55,200 52,500 166,400 175,500 Transportation fees 6,800 6,200 18,700 23,700 Direct costs 25,900 36,600 110,500 107,000 Total $ 100,200 $ 107,000 $ 332,600 $ 345,200

Description of Business (Detail

Description of Business (Details)	9 Months Ended
	Sep. 30, 2016
Description Of Business [Line Items]
Atlas America Public #9 LTD. Formation Date	Jul. 27, 2000
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	$ 18,976,300	$ 18,976,300
Accumulated depletion and impairment	(18,439,300)	(18,439,300)
Gas and oil properties, net	537,000	537,000
Leasehold interests
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	254,600	254,600
Wells and related equipment
Property Plant And Equipment [Line Items]
Total natural gas and oil properties	$ 18,721,700	$ 18,721,700

Derivative Instruments (Narrati

Derivative Instruments (Narrative) (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Derivative [Line Items]
Net derivative assets	$ 0	$ 13,400
ARP | Commodity Hedge | Put Contracts | Accounts Receivable Trade –Affiliate
Derivative [Line Items]
Value allocated to partnership	1,000
Put premium value	$ 2,500

Derivative Instruments (Summary

Derivative Instruments (Summary of Commodity Derivative Activity and Presentation in the 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 oil revenues	$ 300	$ (900)	$ 700	$ 2,200
Gain (loss) subsequent to hedge accounting recognized in gain on mark-to-market derivatives		$ 4,500	$ (100)	$ 4,600

Fair Value of Financial Instr23

Fair Value of Financial Instruments (Assets Measured at Fair Value on a Recurring Basis) (Details) - Commodity Puts	Dec. 31, 2015USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 13,400
Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value Asset	$ 13,400

Certain Relationships and Rel24

Certain Relationships and Related Party Transactions (Narrative) (Details) - MGP and Affiliates	9 Months Ended
	Sep. 30, 2016$ / mo
General and administrative expenses
Related Party Transaction [Line Items]
Monthly Administrative Costs Per Well	75
Supervision fees
Related Party Transaction [Line Items]
Monthly Supervision Fees Per Well	337
Transportation fees
Related Party Transaction [Line Items]
Transportation Fees Rate As Percentage Of Natural Gas Sales Price	13.00%

Certain Relationships and Rel25

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	$ 100,200	$ 107,000	$ 332,600	$ 345,200
Administrative fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	12,300	11,700	37,000	39,000
Supervision fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	55,200	52,500	166,400	175,500
Transportation fees
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	6,800	6,200	18,700	23,700
Direct costs
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 25,900	$ 36,600	$ 110,500	$ 107,000

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 | $	$ 333,900