United States

Securities and Exchange Commission

Washington, D.C. 20549

Form 10-Q

(Mark One)

☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~September~~March 3031, ~~2016~~2017

☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 000-49776

ATLAS AMERICA PUBLIC #9 LTD.

(Name of small business issuer in its charter)

Pennsylvania		25-1867510
(State or other jurisdiction ofincorporation or organization)		(I.R.S. EmployerIdentification No.)
Park Place Corporate Center One
425 Houston Street, Suite 300
1000 Commerce Drive, 4th Floor
Fort Worth, TX		76102
Pittsburgh, PA		15275
(Address of principal executive offices)		(zip code)

Issuer’s telephone number, including area code: (412)-489-0006

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or aan ~~smaller~~emerging ~~reporting~~growth company. See ~~the~~ definitions of “large accelerated filer,”, “accelerated filer,” “~~non-accelerated~~smaller ~~filer~~reporting company,” and “~~smaller~~emerging ~~reporting~~growth company” in Rule 12b-2 of the Exchange Act. ~~(Check one):~~

Large accelerated filer ☐ Accelerated filer ☐ Non-accelerated filer ☐ Smaller reporting company ☑☒ Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

ATLAS AMERICA PUBLIC #9 LTD.

(A Pennsylvania Limited Partnership)

INDEX TO QUARTERLY REPORT

ON FORM 10-Q

		PAGE
PART I.	FINANCIAL INFORMATION (Unaudited)
Item 1:
	Condensed Balance Sheets as of September 30, 2016 and December 31, 2015	3
	Condensed Balance Sheets as of March 31, 2017 and December 31, 2016	3
	Condensed Statements of Operations for the Three and Nine Months ended September 30, 2016 and 2015	4
	Condensed Statements of Operations for the Three Months ended March 31, 2017 and 2016	4
	Condensed Statements of Comprehensive Loss for the Three and Nine Months ended September 30, 2016 and 2015	5
	Condensed Statements of Comprehensive Loss for the Three Months ended March 31, 2017 and 2016	5
	Condensed Statement of Changes in Partners’ Deficit for the Nine Months ended September 30, 2016	6
	Condensed Statement of Changes in Partners’ Deficit for the Three Months ended March 31, 2017	6
	Condensed Statements of Cash Flows for the Nine Months ended September 30, 2016 and 2015	7
	Condensed Statements of Cash Flows for the Three Months ended March 31, 2017 and 2016	7
	Notes to Condensed Financial Statements	8
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1412
Item 4:	Controls and Procedures	2016
PART II	OTHER INFORMATION
Item 1:	Legal Proceedings	2017
Item 6:	Exhibits	2118
SIGNATURES		2219
CERTIFICATIONS

PART I. FINANCIAL INFORMATION

ITEM I FINANCIAL STATEMENTS

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED BALANCE SHEETS

(Unaudited)

	September 30,2016			December 31,2015
	March 31,2017			December 31,2016
ASSETS
Current assets:
Cash	$	-		$	-
Accounts receivable trade-affiliate		3143,~~800~~900			2941,~~600~~700
Current portion of derivative assets		-			13,400
Total current assets		43,900			41,700
Total current assets		31,800			43,000
Gas and oil properties, net		338,500			338,500
Gas and oil properties, net		537,000			537,000
Long-term asset retirement receivable-affiliate		431,200			382,500
Long-term asset retirement receivable-affiliate		333,900			188,100
Total assets	$	813,600		$	762,700
Total assets	$	902,700		$	768,100
LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities:
Accounts payable trade-affiliate	$	~~624~~797,~~500~~600		$	~~302~~718,~~300~~100
Accrued liabilities		135,~~100~~400			1011,~~300~~600
Put premiums payable-affiliate		-			6,200
Total current liabilities		803,000			729,700
Total current liabilities		637,600			318,800
Asset retirement obligations		1,966,000			1,948,300
Asset retirement obligations		1,931,100			1,879,800
Commitments and contingencies (Note 4)
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit		(~~264~~495,~~300~~100	)		(~~181~~480,~~000~~800	)
Limited partners’ deficit (1,500 units)		(1,~~401~~460,~~700~~300	)		(1,~~250~~434,~~200~~500	)
Accumulated other comprehensive income		-			700
Total partners’ deficit		(1,955,400	)		(1,915,300	)
Total partners’ deficit		(1,666,000	)		(1,430,500	)
Total liabilities and partners’ deficit	$	813,600		$	762,700
Total liabilities and partners’ deficit	$	902,700		$	768,100

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months EndedSeptember 30,						Nine Months EndedSeptember 30,
	Three Months EndedMarch 31,
	2016			2015			2016			2015
	2017			2016
REVENUES
Natural gas and oil	$	5586,~~400~~600		$	4741,~~000~~600		$	~~149,200~~		$	~~203,200~~
Gain (loss) on mark-to-market derivatives		-			4,500			(100	)		4,600
Gain on mark-to-market derivatives		-			2,300
Total revenues		5586,~~400~~600			5143,~~500~~900			~~149,100~~			~~207,800~~
COSTS AND EXPENSES
Production		7480,~~100~~600			8175,~~200~~100			~~254,100~~			~~264,200~~
Depletion		-			8,400			-			27,600
Accretion of asset retirement obligations		17,700			17,100
Impairment		-			457,200			-			457,200
General and administrative		28,400			25,600
Accretion of asset retirement obligations		17,000			25,400			51,300			76,300
Total costs and expenses		126,700			117,800
General and administrative		26,100			25,800			78,500			81,000
Net loss	$	(40,100	)	$	(73,900	)
Total costs and expenses		117,200			598,000			383,900			906,300
Allocation of net loss:
Net loss	$	(61,800	)	$	(546,500)		$	(234,800	)	$	(698,500)
Managing general partner	$	(14,300	)	$	(27,100	)
Allocation of net loss:
Limited partners	$	(25,800	)	$	(46,800	)
Managing general partner	$	(21,900	)	$	(221,100)		$	(83,300	)	$	(277,200)
Net loss per limited partnership unit	$	(17	)	$	(31	)
Limited partners	$	(39,900	)	$	(325,400)		$	(151,500	)	$	(421,300)
Net loss per limited partnership unit	$	(27	)	$	(217)		$	(101	)	$	(281)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS

(Unaudited)

	Three Months Ended							~~Nine Months Ended~~
	September 30,							September 30,
	March 31,
	2016					2015		2016			2015
	2017				2016
Net loss	$	(40,100	~~(61,800~~)	)	$	$(73,900	~~(546,500~~)	$	~~(234,800~~	)	$	~~(698,500)~~
Other comprehensive loss:
Difference in estimated hedge gains receivable			-				(1,600)		-			200
Less: reclassification adjustment to net loss of mark-to-market gains on cash flow hedges		-				(200	)
Less: reclassification adjustment for realized (gain) loss of cash flow hedges in net loss			(300	)			900		(700	)		(2,200)
Total other comprehensive loss		-				(200	)
Total other comprehensive loss			(300	)			(700)		(700	)		(2,000)
Comprehensive loss	$	(40,100	)		$	(74,100	)
Comprehensive loss		$	(62,100	)		$	(547,200)	$	(235,500	)	$	(700,500)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ DEFICIT

FOR THE ~~NINE~~THREE MONTHS ENDED

~~September~~March 3031, ~~2016~~2017

(Unaudited)

	ManagingGeneralPartner			LimitedPartners			~~AccumulatedOtherComprehensiveIncome~~		Total		~~Total~~
Balance at December 31, 2015	$	(181,000	)	$	(1,250,200	)	$	700			$	(1,430,500	)
Balance at December 31, 2016	$	(480,800	)	$	(1,434,500	)			$	(1,915,300	)
Participation in revenues, costs and expenses:
Net production expenses		(37,200	)		(67,700	)		-				(104,900	)
Net production revenues		2,100			3,900					6,000
Loss on mark-to-market derivatives		-			(100	)		-				(100	)
Accretion of asset retirement obligations		(6,300	)		(11,400	)				(17,700	)
Accretion of asset retirement obligations		(18,200	)		(33,100	)		-				(51,300	)
General and administrative		(10,100	)		(18,300	)				(28,400	)
General and administrative		(27,900	)		(50,600	)		-				(78,500	)
Net loss		(14,300	)		(25,800	)				(40,100	)
Net loss		(83,300	)		(151,500	)		-				(234,800	)
Balance at March 31, 2017	$	(495,100	)	$	(1,460,300	)			$	(1,955,400	)
Other comprehensive loss		-			-			(700	)			(700	)
Balance at September 30, 2016	$	(264,300	)	$	(1,401,700	)	$	-			$	(1,666,000	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months EndedSeptember 30,
	Three Months EndedMarch 31,
	2016			2015
	2017			2016
Cash flows used in operating activities:
Net loss	$	(~~234~~40,~~800~~100	)	$	(~~698~~73,~~500)~~900	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion		-			27,600
Accretion of asset retirement obligations		17,700			17,100
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	)		654,~~500~~700
Increase in asset retirement receivable-affiliate		(~~145~~48,~~800~~700	)		(~~129~~48,600)	)
Increase in accounts payable trade-affiliate		~~322~~79,~~200~~500			~~202~~95,~~000~~300
Increase in accrued liabilities		2,800			3,300
(Decrease) increase in accrued liabilities		(6,200	)		5,400
Net cash used in operating activities		-			(200)
Net cash provided by operating activities		-			-
Cash flows from investing activities:
Net cash provided by investing activities		-			~~200~~-
		-			200
Cash flows from financing activities:
Net cash used in financing activities		-			-
Net change in cash		-			-
Cash at beginning of period		-			-
Cash at end of period	$	-		$	-

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED NOTES TO FINANCIAL STATEMENTS

~~September~~March 3031, ~~2016~~2017

(Unaudited)

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 isalso asponsors ~~leading sponsor~~ and ~~manager~~manages of tax-advantaged investment partnerships, in which it co-invests to finance a portion of its natural gas and oil production activities. Titan is the successor to the business and operations of Atlas Resource Partners, L.P. (“ARP”), a Delaware limited partnership organized in 2012. Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to Atlas America Public #9 LTD.

Atlas Energy Group, LLC (“Atlas Energy Group”; ~~OTC~~OTCQX: ATLS) is a publicly traded company and ~~operates~~manages 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~~2017. 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~~had 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 MGP intends, as necessary, to continue the Partnership’s operations and to fund the Partnership’s obligations; however, the uncertainties of Titan’s and the MGP’s liquidity and capital resources (as further described below) raise substantial doubt about Titan’s and the MGP’s ability to continue as a going concern, which further raises substantial doubt about the Partnership’s ability to continue as a going concern. If Titan is unsuccessful in taking actions to resolve its liquidity issues (as further described below), the MGP’s ability to continue the Partnership’s operations may be further impacted and may make it uneconomical for the Partnership to produce its wells until they are depleted as originally intended. 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.

MGP’s Liquidity, Capital Resources, and Ability to Continue as a Going Concern

The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under Titan’s credit facilities. The MGP’s primary cash requirements are operating expenses, payments to Titan for 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 Titan’s 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 continued to remain low in 2017. 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, have negatively impacted Titan’s and the MGP’s ability to remain in compliance with the covenants under its credit facilities.

Titan was not in compliance with certain of the financial covenants under its credit facilities as of December 31, 2016, as well as the requirement to deliver audited financial statements without a going concern qualification. Titan and the MGP do not currently have sufficient liquidity to repay all of Titan’s outstanding indebtedness, and as a result, there is substantial doubt regarding Titan’s and the MGP’s ability to continue as a going concern.

On April 19, 2017, Titan entered into a third amendment to its first lien credit facility in an attempt to ameliorate some of its liquidity concerns. The amendment provides for, among other things, waivers of non-compliance, increases in certain financial covenant ratios and scheduled decreases in Titan’s borrowing base. In addition, Titan expects that it will sell a significant amount of non-core assets in the near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. The lenders’ waivers are subject to revocation in certain circumstances, including the exercise of remedies by junior lenders (including pursuant to Titan’s second lien credit facility), the failure to extend the 180-day standstill period under the intercreditor agreement at least 15 business days prior to its expiration, and the occurrence of additional events of default under the first lien credit facility.

On April 21, 2017, the lenders under the Titan’s second lien credit facility delivered a notice of events of default and reservation of rights, pursuant to which they noticed events of default related to financial covenants and the failure to deliver financial statements without a “going concern” qualification. The delivery of such notice began the 180-day standstill period under the intercreditor agreement, during which the lenders under the second lien credit facility are prevented from pursuing remedies against the collateral securing Titan’s obligations under the second lien credit facility. The lenders have not accelerated the payment of amounts outstanding under the second lien credit facility.

~~Liquidity~~Titan continually monitors the capital markets and ~~Capital~~the ~~Resources~~MGP’s 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, Titan 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. Titan is evaluating various options, but there is no certainty that Titan will be able to implement any such options, and cannot provide any assurances that any refinancing or changes in its debt or equity capital structure would be possible or that additional equity or debt financing could be obtained on acceptable terms, if at all, and such options may result in a wide range of outcomes for Titan’s stakeholders. In addition, Titan expects that it will sell a significant amount of non-core assets in the ~~MGP~~near future to comply with the requirements of its first lien credit facility amendment and to attempt to enhance its liquidity. However, there is no guarantee that the proceeds Titan receives for any asset sale will satisfy the repayment requirements under its first lien credit facility.

~~The MGP~~Titan’s ~~primary~~Appalachia 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.Divestiture

~~The~~On ~~MGP~~May ~~has~~4, ~~historically funded its operations~~2017, ~~acquisitions~~Titan ~~and~~entered ~~cash~~into ~~distributions~~a ~~primarily~~definitive ~~through~~agreement ~~cash~~to ~~generated~~sell ~~from~~its ~~operations,~~conventional ~~amounts~~assets ~~available~~to ~~under~~Diversified ~~its~~Gas ~~credit~~& ~~facilities~~Oil, ~~and~~PLC ~~equity~~(“Diversified”), ~~and~~for ~~debt~~$84.2 ~~offerings~~million. The ~~MGP’s~~transaction ~~future~~includes ~~cash~~the ~~flows~~sale ~~are subject to a number~~ of ~~variables~~approximately 8,400 ~~including~~ oil and ~~natural~~ gas ~~prices.~~wells ~~Prices~~across ~~for~~Pennsylvania, ~~oil~~Ohio, ~~and~~Tennessee, ~~natural~~New ~~gas~~York ~~began~~and toWest ~~decline~~Virginia, ~~significantly~~along ~~during~~with the ~~fourth~~associated ~~quarter~~infrastructure. ofTitan ~~2014~~will ~~and~~retain ~~have~~its ~~continued~~Utica toShale ~~decline~~position, ~~and~~Indiana ~~remain~~assets ~~low~~and inWest ~~2016.~~Virginia ~~These~~coalbed ~~lower~~methane ~~commodity~~assets ~~prices~~in ~~have~~the ~~negatively~~region. The ~~impacted~~transaction ~~the~~is ~~MGP’s~~subject ~~revenues,~~to ~~earnings~~customary ~~and~~closing ~~cash~~conditions, ~~flows.~~has ~~Sustained~~an ~~low~~effective ~~commodity~~date ~~prices~~of ~~could~~April ~~have~~1, a2017 ~~material~~ and ~~adverse~~is ~~effect~~expected onto ~~the~~close ~~MGP’s~~in ~~liquidity~~June ~~position~~2017. InThe ~~addition,~~net ~~challenges~~proceeds ~~with~~will ~~the~~be ~~MGP’s~~used ~~ability~~ to ~~raise~~repay ~~capital~~a ~~through~~portion ~~its~~of ~~drilling~~outstanding ~~partnership~~borrowings ~~program,~~under ~~either~~Titan’s asfirst alien ~~result~~credit offacility. ~~downturn~~The intransaction ~~commodity~~will ~~prices~~significantly orimprove ~~other~~Titan’s ~~difficulties~~first ~~affecting~~lien ~~the~~credit ~~fundraising~~facility ~~channel,~~metrics ~~could~~and ~~negatively~~is ~~impact~~expected ~~the~~to ~~MGP’s~~fulfill ~~ability~~its borrowing base step down to ~~remain~~$360 inmillion, ~~compliance~~which ~~with~~is ~~the~~scheduled ~~covenants~~to ~~under~~occur ~~its~~on ~~credit~~August ~~facilities~~31, 2017.

IfThe ~~the~~assets ~~MGP~~Titan ishas ~~unable~~agreed to ~~remain~~sell into ~~compliance~~Diversified ~~with~~include ~~the covenants under~~ its ~~credit~~indirect ~~facilities,~~interests ~~absent~~in ~~relief~~the ~~from~~Partnership’s ~~its~~assets. ~~lenders,~~Titan asexpects ~~applicable,~~that the MGP ~~may~~will beeffectuate ~~forced~~one ~~to repay~~ or ~~refinance~~more ~~such~~transactions ~~indebtedness.~~involving ~~Upon~~ the ~~occurrence~~Partnership ofin anconnection ~~event~~with ofthe ~~default~~sale, ~~the~~pursuant ~~lenders~~to ~~under~~which the ~~MGP~~Partnership’s ~~credit~~assets ~~facilities,~~will asbe ~~applicable,~~segregated ~~could elect~~ to ~~declare~~allow ~~all~~Titan ~~amounts outstanding immediately due and payable and the lenders could terminate all commitments~~ to ~~extend~~transfer ~~further credit. If an event of default occurs (including if~~ the ~~MGPs~~MGP’s ~~borrowing~~equity ~~base~~interests isin ~~redetermined below its current outstanding borrowings and they are unable to repay~~ the ~~deficiency~~Partnership orwith ~~deposit~~respect ~~additional collateral~~ to ~~eliminate such deficiency), or if other debt agreements cross-default, and~~ the ~~lenders~~Partnership’s ~~under~~assets. ~~the~~Following ~~affected~~Titan’s ~~debt agreements accelerate the maturity of any loans or other debt outstanding~~transfer, ~~the~~Diversified ~~MGP~~ will ~~not~~be ~~have~~the ~~sufficient~~managing ~~liquidity~~general topartner ~~repay all of its outstanding indebtedness,~~ and asoperator awith ~~result,~~respect ~~there~~to ~~would be substantial doubt regarding~~ the ~~MGP’s ability to continue as a going concern~~assets.

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.

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.

Derivative Instruments

The Partnership’s MGP entered into certain financial contracts to manage the Partnership’s exposure to movement in commodity prices. On January 1, 2015, the Partnership discontinued hedge accounting through de-designation for all of its existing commodity derivatives which were qualified as hedges. As such, subsequent changes in fair value after December 31, 2014 of these derivatives were recognized immediately within gain (loss) on mark-to-market derivatives in the Partnership’s statements of operations, while the fair values of the instruments recorded in accumulated other comprehensive income as of December 31, 2014 were reclassified to the statements of operations in the periods in which the respective derivative contracts settled. During the three months ended March 31, 2017, the Partnership did not have any derivative activity as all derivative contracts have matured. During the three months ended March 31, 2016, the Partnership recorded $200 as a gain reclassified from accumulated other comprehensive income into natural gas and oil revenues and $2,300 as a gain subsequent to hedge accounting recognized in gain on mark-to-market derivatives.

Gas and Oil Properties

The following is a summary of gas and oil properties at the dates indicated:

	September 30,2016			December 31,2015
	March 31,2017			December 31,2016
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~~637,~~300~~800	)		(18,~~439~~637,~~300~~800	)
Gas and oil properties, net	$	~~537~~338,~~000~~500		$	~~537~~338,~~000~~500

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 balance sheets at ~~September~~March 3031, ~~2016~~2017 and December 31, ~~2015~~2016 was ~~primarily~~entirely related to the estimated salvage value of such properties. The estimated salvage values were based on the MGP’s historical experience in determining such values.

Recently Issued Accounting Standards

In ~~February~~May ~~2016~~2014, the FASB updated the accounting guidance related to ~~leases~~revenue recognition. The updated accounting guidance ~~requires~~provides ~~lessees~~a single, contract-based revenue recognition model to ~~recognize~~help aimprove ~~lease~~financial ~~asset~~reporting ~~and~~by ~~liability~~providing atclearer ~~the~~guidance ~~commencement~~on ~~date~~when ofan ~~all~~entity ~~leases~~should ~~(with~~recognize revenue, and by reducing the ~~exception~~number of ~~short-term~~standards ~~leases),~~to ~~initially~~which ~~measured~~an atentity has to refer. In July 2015, the ~~present~~FASB ~~value~~voted ofto defer the ~~lease~~effective ~~payments~~date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance isprovides ~~effective~~companies ~~for~~with ~~the~~alternative ~~Partnership~~methods asof adoption. We are evaluating the impact of ~~January~~this 1,updated ~~2019~~accounting ~~and~~guidance ~~requires~~on aour ~~modified~~consolidated ~~retrospective~~financial ~~transition~~statements. ~~approach~~This ~~for~~accounting ~~leases~~guidance ~~existing~~will ~~at,~~require orthat ~~entered~~our ~~into~~revenue ~~after,~~recognition policy disclosures include further detail regarding our performance obligations as to the ~~beginning~~nature, amount, timing, and estimates of ~~the~~revenue ~~earliest~~and ~~period~~cash ~~presented~~flows generated from our contracts with customers. ~~The~~ ~~Partnership~~We isare ~~currently~~still in the process of determining ~~the~~whether ~~impact~~or ~~that~~not we will use the ~~updated~~retrospective ~~accounting~~method ~~guidance~~or ~~will~~the ~~have~~modified onretrospective ~~its~~approach ~~financial~~to ~~statements~~implementation.

InNOTE ~~August~~3 ~~2014,~~- ~~the~~CERTAIN ~~FASB~~RELATIONSHIPS ~~updated~~AND ~~the~~RELATED ~~accounting~~PARTY ~~guidance~~TRANSACTIONS 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.

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 EndedSeptember 30,				Nine Months EndedSeptember 30,
	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.

NOTE 4 - FAIR VALUE OF FINANCIAL INSTRUMENTS

The Partnership uses a market approach fair value methodology to value for its outstanding derivative contracts. The fair value of a financial instrument depends on a number of factors, including the availability of observable market data over the contractual term of the underlying instrument. The Partnership separates the fair value of its financial instruments into three levels (Levels 1, 2 and 3) based on its assessment of the availability of observable market data and the significance of non-observable data used to determine fair value. As of September 30, 2016 and December 31, 2015, all derivative financial instruments were classified as Level 2.

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

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 EndedSeptember 30,

Nine Months EndedSeptember 30,

Three Months EndedMarch 31,

2016

2015

2016

2015

2017

2016

Administrative fees

1213,~~300~~500

11,~~700~~600

~~37,000~~

~~39,000~~

Supervision fees

5560,~~200~~600

52,~~500~~200

~~166,400~~

~~175,500~~

Transportation fees

69,~~800~~400

65,~~200~~700

~~18,700~~

~~23,700~~

Direct costs

25,~~900~~500

3631,~~600~~200

~~110,500~~

~~107,000~~

Total

~~100~~109,~~200~~000

~~107~~100,~~000~~700

~~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~~revenues due to the MGP.

~~NOTE 6 - COMMITMENTS AND CONTINGENCIES~~ 11

NOTE 4 - 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~~March 3031, ~~2016~~2017, the MGP has withheld $~~333~~431,~~900~~200 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.

ITEM 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (UNAUDITED)

Forward-Looking Statements

When used in this Form 10-Q, the words “believes”, “anticipates,” “expects” and similar expressions are intended to identify forward-looking statements. Such statements are subject to certain risks and uncertainties, which could cause actual results to differ materially from the results stated or implied in this document. Readers are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date hereof. We undertake no obligation to publicly release the results of any revisions to forward-looking statements which we may make to reflect events or circumstances after the date of this Form 10-Q or to reflect the occurrence of unanticipated events.

General

Atlas America Public #9 LTD. (“we”, “us” or 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 is an independent developer and producer of natural gas, crude oil, and natural gas liquids, with operations in basins across the United States. Titan isalso asponsors ~~leading sponsor~~ and ~~manager~~manages of tax-advantaged investment partnerships, in which it co-invests to finance a portion of its natural gas and oil production activities. Titan is the successor to the business and operations of Atlas Resource Partners, L.P. (“ARP”), a Delaware limited partnership organized in 2012. Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our” and “our company”, refer to Atlas America Public #9 LTD.

Atlas Energy Group, LLC (“Atlas Energy Group”; ~~OTC~~OTCQX: ATLS) is a publicly traded company and ~~operates~~manages Titan and the MGP through a 2% preferred member interest in Titan.

We have drilled and currently operate 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.

WeThe ~~intend~~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 ~~continue~~market through affiliated and/or third-party gas gathering systems. The Partnership intends to produce ~~our~~its wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. WeThe ~~expect~~Partnership ~~that~~does nonot ~~other~~expect ~~wells~~to ~~will~~drill beadditional ~~drilled~~wells and expects no additional funds will be required for drilling.

~~Atlas~~The ~~Resource~~economic ~~Partners~~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, Lcompleting or reworking a well).P. ~~Restructuring~~There are numerous uncertainties inherent in estimating quantities of proven reserves and ~~Chapter~~in 11projecting ~~Bankruptcy~~future ~~Proceedings~~net revenues.

OnThe ~~July 27,~~prices ~~2016,~~at ~~ARP~~which the Partnership’s natural gas and ~~certain~~oil ofwill ~~its~~be ~~subsidiaries,~~sold ~~including~~are uncertain and the ~~MGP,~~Partnership ~~filed~~is ~~voluntary~~not ~~petitions~~guaranteed ~~for~~a ~~relief~~specific ~~under~~price ~~Chapter~~for 11the sale of ~~the~~its ~~United~~production. ~~States~~Changes ~~Bankruptcy~~in ~~Code~~natural ~~(“Chapter~~gas ~~11”)~~and inoil ~~the~~prices ~~United~~have ~~States~~a ~~Bankruptcy~~significant ~~Court~~impact ~~for~~on the ~~Southern~~Partnership’s ~~District~~cash offlow ~~New~~and ~~York (~~the ~~“Bankruptcy~~value ~~Court”)~~of its reserves. ~~The~~Lower ~~cases~~natural ~~commenced~~gas ~~thereby~~and ~~were~~oil ~~jointly~~prices ~~administered~~may ~~under~~not only decrease the ~~caption~~Partnership’s ~~“In~~revenues, ~~re:~~but ~~ATLAS~~also ~~RESOURCE~~may ~~PARTNERS,~~reduce ~~L.P.,~~the etamount alof natural gas and oil that the Partnership can produce economically.”

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

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.

MGP’s Liquidity, ~~and~~ Capital Resources, ofand ~~the~~Ability ~~MGP~~to Continue as a Going Concern

The MGP’s primary sources of liquidity are cash generated from operations, capital raised through its drilling partnership program, and borrowings under ~~its~~Titan’s credit facilities. The MGP’s primary cash requirements are operating expenses, payments to Titan for 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~~Titan’s 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~~2017. 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. 13

15Titan was not in compliance with certain of the financial covenants under its credit facilities as of December 31, 2016, as well as the requirement to deliver audited financial statements without a going concern qualification. Titan and the MGP do not currently have sufficient liquidity to repay all of Titan’s outstanding indebtedness, and as a result, there is substantial doubt regarding Titan’s and the MGP’s ability to continue as a going concern.

~~The~~On ~~MGP~~April ~~continually~~19, ~~monitors~~2017, ~~the~~Titan ~~capital~~entered ~~markets~~into ~~and~~a ~~our~~third ~~capital~~amendment ~~structure~~to ~~and~~its ~~may~~first ~~make~~lien ~~changes~~credit facility in an attempt to ameliorate some of its ~~capital~~liquidity ~~structure~~concerns. ~~from~~The ~~time~~amendment toprovides ~~time~~for, ~~with~~among ~~the~~other ~~goal~~things, waivers of ~~maintaining~~non-compliance, increases in certain financial ~~flexibility,~~covenant ~~preserving~~ratios orand ~~improving~~scheduled ~~liquidity,~~decreases ~~strengthening~~in ~~its~~Titan’s ~~balance~~borrowing ~~sheet~~base. In addition, ~~meeting~~Titan expects that it will sell a significant amount of non-core assets in the near future to comply with the requirements of its ~~debt~~first ~~service~~lien ~~obligations~~credit facility amendment and~~/or~~ ~~achieving~~to ~~cost~~attempt ~~efficiency~~to enhance its liquidity. ~~For~~ ~~example,~~The ~~the~~lenders’ ~~MGP~~waivers ~~could~~are ~~pursue~~subject ~~options~~to ~~such~~revocation asin ~~refinancing~~certain circumstances, ~~restructuring~~including orthe ~~reorganizing~~exercise ~~its~~of ~~indebtedness~~remedies orby ~~capital~~junior ~~structure~~lenders or(including ~~seek~~pursuant to ~~raise~~Titan’s ~~additional~~second ~~capital~~lien ~~through~~credit ~~debt~~facility), orthe ~~equity~~failure ~~financing~~ to ~~address~~extend ~~its~~the ~~liquidity~~180-day ~~concerns~~standstill period under the intercreditor agreement at least 15 business days prior to its expiration, and ~~high~~the ~~debt~~occurrence ~~levels~~of additional events of default under the first lien credit facility.

~~The~~ ~~MGP~~On ~~also continues to implement various cost saving measures to reduce its capital~~April 21, ~~operating and general and administrative costs~~2017, ~~including~~the ~~renegotiating~~lenders ~~contracts~~under ~~with~~the ~~contractors,~~Titan’s ~~suppliers~~second ~~and~~lien ~~service~~credit ~~providers,~~facility ~~reducing~~delivered ~~the~~a ~~number~~notice of ~~staff~~events ~~and~~of ~~contractors~~default and ~~deferring~~reservation ~~and~~of ~~eliminating~~rights, ~~discretionary~~pursuant ~~costs. The MGP will continue~~ to bewhich ~~opportunistic~~they ~~and~~noticed ~~aggressive~~events inof ~~managing~~default ~~its~~related ~~cost~~to ~~structure~~financial covenants and, inthe ~~turn,~~failure ~~its~~to ~~liquidity~~deliver tofinancial ~~meet~~statements ~~its~~without ~~capital~~a ~~and~~“going ~~operating~~concern” ~~needs~~qualification. The ~~MGP~~delivery ~~cannot provide any assurances that any~~ of ~~these~~such ~~efforts~~notice ~~will~~began bethe ~~successful~~180-day orstandstill ~~will~~period ~~result~~under inthe ~~cost~~intercreditor ~~reductions~~agreement, orduring ~~cash~~which ~~flows or~~ the ~~timing~~lenders ofunder ~~any~~the ~~such~~second ~~cost~~lien ~~reductions~~credit orfacility ~~additional~~are ~~cash~~prevented ~~flows.~~from Itpursuing isremedies ~~also~~against ~~possible~~the ~~additional~~collateral ~~adjustments~~securing ~~to the MGP~~Titan’s ~~plan~~obligations ~~and~~under ~~outlook~~the ~~may~~second ~~occur~~lien ~~based~~credit ~~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~~facility. In ~~addition,~~The tolenders ~~the~~have ~~extent~~not ~~commodity~~accelerated ~~prices remain low or decline further, or~~ the ~~MGP~~payment ~~experiences disruptions in its longer-term access to or cost~~ of ~~capital,~~amounts ~~the~~outstanding ~~MGP’s~~under ~~ability to fund future capital expenditures, growth projects or~~ the ~~Partnership’s~~second ~~operations~~lien ~~may~~credit ~~be further impacted~~facility.

Titan continually monitors the capital markets and the MGP’s 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, Titan 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. Titan is evaluating various options, but there is no certainty that Titan will be able to implement any such options, and cannot provide any assurances that any refinancing or changes in its debt or equity capital structure would be possible or that additional equity or debt financing could be obtained on acceptable terms, if at all, and such options may result in a wide range of outcomes for Titan’s stakeholders. In addition, Titan expects that it will sell a significant amount of non-core assets in the near future to comply with the requirements of its expected first lien credit facility amendment and to attempt to enhance its liquidity. However, there is no guarantee that the proceeds Titan receives for any asset sale will satisfy the repayment requirements under its first lien credit facility.

Titan’s Appalachia Divestiture

On May 4, 2017, Titan entered into a definitive agreement to sell its conventional assets to Diversified Gas & Oil, PLC (“Diversified”), for $84.2 million. The transaction includes the sale of approximately 8,400 oil and gas wells across Pennsylvania, Ohio, Tennessee, New York and West Virginia, along with the associated infrastructure. Titan will retain its Utica Shale position, Indiana assets and West Virginia coalbed methane assets in the region. The transaction is subject to customary closing conditions, has an effective date of April 1, 2017 and is expected to close in June 2017. The net proceeds will be used to repay a portion of outstanding borrowings under Titan’s first lien credit facility. The transaction will significantly improve Titan’s first lien credit facility metrics and is expected to fulfill its borrowing base step down to $360 million, which is scheduled to occur on August 31, 2017.

The assets Titan has agreed to sell to Diversified include its indirect interests in the Partnership’s assets. Titan expects that the MGP will effectuate one or more transactions involving the Partnership in connection with the sale, pursuant to which the Partnership’s assets will be segregated to allow Titan to transfer the MGP’s equity interests in the Partnership with respect to the Partnership’s assets. Following Titan’s transfer, Diversified will be the managing general partner and operator with respect to the assets.

Overview

The following discussion provides information to assist in understanding our financial condition and results of operations. Our operating cash flows are generated from our wells, which produce primarily natural gas, but also some oil. Our produced natural gas and oil is then delivered to market through affiliated and/or third-party gas gathering systems. Our ongoing operating and maintenance costs have been and are expected to be fulfilled through revenues from the sale of our natural gas and oil production. We pay our MGP, as operator, a monthly well supervision fee, which covers all normal and regularly recurring operating expenses for the production and sale of natural gas and oil such as:

•

well tending, routine maintenance and adjustment;

•

reading meters, recording production, pumping, maintaining appropriate books and records; and

•

preparation of reports for us and government agencies.

The well supervision fees, however, do not include costs and expenses related to the purchase of certain equipment, materials and brine disposal. If these expenses are incurred, we pay cost for third-party services, materials and a competitive charge for services performed directly by our MGP or its affiliates. Also, beginning one year after each of our wells has been placed into production, our MGP, as operator, may retain $200 per month, per well, to cover the estimated future plugging and abandonment costs of the well. As of ~~September~~March 3031, ~~2016~~2017, our MGP has withheld $~~333~~431,~~900~~200 of net production revenues for this purpose.

Markets and Competition

The availability of a ready market for natural gas and oil produced by us, and the price obtained, depends on numerous factors beyond our control, including the extent of domestic production, imports of foreign natural gas and oil, political instability or terrorist acts in gas and oil producing countries and regions, market demand, competition from other energy sources, the effect of federal regulation on the sale of natural gas and oil in interstate commerce, other governmental regulation of the production and transportation of natural gas and oil and the proximity, availability and capacity of pipelines and other required facilities. Our MGP is responsible for selling our production. During 2016 and 2015, we experienced no problems in selling our natural gas and oil. Product availability and price are the principal means of competing in selling natural gas and oil production. While it is impossible to accurately determine our comparative position in the industry, we do not consider our operations to be a significant factor in the industry.

Results of Operations

The following table sets forth information relating to our production revenues, volumes, sales prices, and production costs ~~and depletion~~ during the periods indicated:

	Three Months EndedSeptember 30,						Nine Months EndedSeptember 30,
	Three Months EndedMarch 31,
	2016			2015			2016			2015
	2017			2016
Production revenues (in thousands):
Gas	$	4872		$	42		$	~~133~~		$	~~178~~
Oil		715			5-			16			25
Total	$	5587		$	4742		$	~~149~~		$	~~203~~
Production volumes:
Gas (mcf/day) (1)		~~348~~259			~~329~~316			~~338~~			~~364~~
Oil (bbl/day) (1)		24			1-			2			2
Total (mcfe/day) (1)		~~360~~283			~~335~~316			~~350~~			~~376~~
Average sales prices: (2)
Gas (per mcf) (1)	$	13.4809		$	1.3945		$	~~1.43~~		$	~~1.80~~
Oil (per bbl) (1)	$	4237.3883		$	~~50.26~~-		$	~~40.10~~		$	~~48.85~~
Production costs:
As a percent of revenues		~~134~~93	%		~~173~~180	%		~~170~~	%		~~130~~	%
Per mcfe (1)	$	23.2315		$	2.6361		$	~~2.67~~		$	~~2.58~~
Depletion per Mcfe	$	-		$	0.27		$	-		$	0.27

(1) “Mcf” represents thousand cubic feet, “mcfe” represents thousand cubic feet equivalent, and “bbl” represents barrels. Bbl is converted to mcfe using the ratio of ~~nine~~six mcfs to one bbl.

(2)	Average sales prices represent accrual basis pricing.

Natural Gas Revenues. Our natural gas revenues were $4772,~~400~~000 and $4241,~~100~~600 for the three months ended ~~September 30~~March 31, ~~2016~~2017 and ~~2015~~2016, respectively, an increase of $530,~~300~~400 (1373%). The $530,~~300~~400 increase in natural gas revenues for the three months ended ~~September 30~~March 31, ~~2016~~2017 as compared to the prior year similar period was attributable to a $238,~~900~~300 increase in our natural gas sales prices ~~after the effect of financial hedges,~~ which were driven by market conditions, ~~and~~partially offset by a $27,~~400~~900 ~~increase~~decrease in production volumes. Our production volumes ~~increased~~decreased to ~~348~~259 mcf per day for the three months ended ~~September 30~~March 31, ~~2016~~2017 from ~~329~~316 mcf per day for the three months ended ~~September 30~~March 31, ~~2015~~2016, ana ~~increase~~decrease of 1957 mcf per day (618%). The overall ~~increase~~decrease in natural gas production volumes for the three months ended ~~September~~March 3031, ~~2016~~2017 as compared to the prior year similar period is due to ~~additional~~the ~~wells~~normal ~~producing~~decline ~~during~~inherent in the ~~current~~life ~~three~~of ~~month~~a ~~period~~well.

~~Our~~Oil ~~natural gas revenues were $132,700 and $178,500 for the nine months ended September 30, 2016 and 2015, respectively, a decrease of $45,800 (26%)~~Revenues. ~~The~~We ~~$45,800~~drilled ~~decrease~~wells inprimarily ~~natural gas revenues for the nine months ended September 30, 2016 as compared~~ to ~~the~~produce ~~prior year similar period was attributable to a $33,500 decrease in our~~ natural gas ~~sales prices after the effect of financial hedges~~, ~~which~~rather ~~were~~than ~~driven by market conditions~~oil, ~~and~~but asome ~~$12,300~~wells ~~decrease~~have inlimited ~~production~~oil ~~volumes~~production. Our ~~production~~oil ~~volumes~~revenues ~~decreased~~were ~~to 338 mcf per day for the nine months ended September 30~~$14,600 ~~2016 from 364 mcf per day~~ for the ~~nine~~three months ended ~~September 30,~~March ~~2015~~31, a2017. ~~decrease~~Our ofproduction 26volumes ~~mcf~~were ~~per day (7%)~~4.28 ~~The~~bbls ~~overall~~per ~~decrease~~day ~~in natural gas production volumes~~ for the ~~nine~~three months ended ~~September 30~~March 31, 2016 as compared to the prior year similar period resulted primarily less wells producing during the current nine month period compared to the prior year and from the normal decline inherent in the life of a well2017.

Oil Revenues. We drilled wells primarily to produce natural gas, rather than oil, but some wells have limited oil production. Our oil revenues were $8,000 and $4,900 for the three months ended September 30, 2016 and 2015, respectively, an increase of $3,100 (63%). The $3,100 increase in oil revenues for the three months ended September 30, 2016 as compared to the prior year similar period was attributable to a $4,500 increase in production volumes partially offset by a $1,400 decrease in oil prices. Our production volumes increased to 2.04 bbls per day for the three months ended September 30, 2016 from 1.06 bbls per day for the three months ended September 30, 2015, an increase of 0.98 bbls per day (92%). 15

~~Our~~Gain ~~oil~~on ~~revenues~~Mark-to-Market ~~were~~Derivatives. ~~$16,500~~We ~~and~~recognized ~~$24,700~~changes ~~for~~in ~~the~~fair ~~nine~~value ~~months~~of ~~ended~~our ~~September 30,~~derivatives ~~2016~~immediately ~~and~~within ~~2015, respectively, a decrease of $8,200~~ (~~33%~~loss). ~~The~~gain ~~$8,200~~on ~~decrease in oil revenues for the nine months ended September 30, 2016 as compared~~ mark-to-market ~~the~~derivatives ~~prior~~on ~~year~~our ~~similar~~condensed ~~period~~statements ~~was~~of ~~attributable to a $4,600 decrease in production volumes and a $3,600 decrease in oil prices~~operations. ~~Our~~As ~~production~~of ~~volumes~~December ~~decreased to 1.50 bbls per day for the nine months ended September 30~~31, 2016, ~~from~~all ~~1.86~~derivative ~~bbls~~contracts ~~per~~have ~~day~~matured ~~for~~and ~~the~~we ~~nine~~have ~~months~~not ~~ended~~entered ~~September 30,~~into ~~2015,~~any anew ~~decrease of 0~~contracts.~~36 bbls per day (19%).~~

17We recognized a gain on mark-to-market derivatives of $2,300 for the three months ended March 31, 2016. This change was due to changes in mark-to-market values primarily related to the change in natural gas prices during the three months ended March 31, 2016.

~~(Loss)~~Costs ~~Gain~~and onExpenses. ~~Mark-to-Market~~Production ~~Derivatives.~~expenses Wewere ~~recognize~~$80,600 ~~changes~~and in$75,100 ~~fair~~for ~~value~~the ofthree ~~our~~months ~~derivatives~~ended ~~immediately~~March ~~within~~31, 2017 and 2016, respectively, an increase of $5,500 (~~loss~~7%). ~~gain~~This onincrease ~~mark-~~was primarily due to~~-market~~ ~~derivatives~~an onincrease ~~our~~in ~~condensed~~well ~~statements~~supervision offees ~~operations~~during the three months ended March 31, 2017.

WeGeneral ~~recognized~~and aadministrative ~~loss~~expenses ~~on mark-to-market derivatives of $100~~ for the ~~nine~~three months ended ~~September~~March 3031, ~~2016~~2017 and a2016 ~~gain~~were ~~on mark-to-market derivatives of~~ $428,~~500~~400 and $425,600, ~~for~~respectively, ~~the~~an ~~three~~increase ~~and~~of ~~nine months ended September 30~~$2,800 ~~2015, respectively~~(11%). These ~~changes~~expenses ~~were~~include ~~due~~third-party tocosts ~~changes~~for inservices ~~mark-to-market~~as ~~values~~well ~~primarily~~as ~~related to~~ the ~~change~~monthly inadministrative ~~natural~~fees ~~gas~~charged ~~prices~~by ~~during~~our ~~the periods~~MGP.

~~Costs~~Cash ~~and~~Flows ~~Expenses~~Overview. ~~Production~~There ~~expenses~~ were ~~$74,100~~no ~~and~~cash ~~$81,200~~flows ~~for~~from ~~the~~operating ~~three~~activities ~~months~~for ~~ended~~cash ~~September 30,~~receipts ~~2016~~ and ~~2015,~~disbursements ~~respectively,~~attributable ~~a decrease of $7,100 (9%). This decrease was primarily due~~ to aour ~~decrease~~normal inmonthly ~~direct~~operating ~~costs~~cycle ~~during~~for ~~the~~gas ~~three~~and ~~months~~oil ~~ended September 30~~production, ~~2016. Production~~lease ~~expenses~~operating ~~were $254~~expenses,~~100~~ ~~and $264~~gathering,~~200~~ ~~for~~processing ~~the nine months ended September 30, 2016~~ and ~~2015,~~transportation ~~respectively~~expenses, aseverance ~~decrease of $10~~taxes,~~100~~ ~~(4%).~~general ~~This decrease was primarily due to a combination of a decrease in transportation charges~~ and ~~supervision~~administrative ~~fees~~expenses.

~~General~~There ~~and~~was ~~administrative~~no ~~expenses~~cash ~~for~~provided ~~the~~by ~~three~~investing ~~months~~activities ~~ended~~for ~~September 30, 2016 and 2015 were $26,100 and $25,800, respectively, an increase of $300 (1%). For~~ the ~~nine~~three months ended ~~September 30,~~March ~~2016 and 2015~~31, ~~these~~2017 ~~expenses were $78,500~~ and ~~$81,000, respectively, a decrease of $2,500 (3%)~~2016. ~~These expenses include third-party costs for services as well as the monthly administrative fees charged by our MGP.~~

~~For~~There ~~the three and nine months ended September 30, 2016, there~~ was no ~~depletion~~cash ~~recorded~~used ~~due to the recent significant declines~~ in ~~commodity~~financing ~~prices~~activities ~~and~~for ~~associated previously recorded impairment charges. Therefore,~~ the ~~remaining net book value of gas and oil properties on our condensed balance sheet at September 30, 2016 was primarily related to the estimated salvage value of such properties. For the~~ three ~~and nine~~ months ended ~~September~~March 3031, ~~2015,~~2017 ~~depletion~~or ~~of gas and oil properties as a percentage of gas and oil revenues was 18% and 14%, respectively~~2016.

~~Liquidity,~~Our ~~Capital~~MGP ~~Resources~~may withhold funds for future plugging and ~~Ability~~abandonment costs. Through March 31, 2017, our MGP has withheld $431,200 of funds for this purpose. Any additional funds, if required, will be obtained from production revenues or borrowings from our MGP or its affiliates, which are not contractually committed to ~~Continue~~make asloans ato ~~Going~~us. ~~Concern~~The amount that we may borrow at any one time may not at any time exceed 5% of our total subscriptions, and we will not borrow from third-parties.

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.

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.

Cash Flows Overview.

Cash used by operating activities for nine months ended September 30, 2016 decreased $200 to $0 as compared to $200 for the nine months ended September 30, 2015. This was mostly due to a decrease in the change in accounts receivable trade-affiliate of $67,700, a decrease in net earnings before depletion, impairment, accretion, and non-cash gain on derivative value of $35,600, a decrease in the asset retirement receivable-affiliate of $16,200, and a decrease in the change in accrued liabilities of $500. The decrease was offset by an increase in the change in accounts payable trade-affiliate of $120,200 for the nine months ended September 30, 2016 compared to the period ended September 30, 2015.

There was no cash provided by investing activities for the nine months ended September 30, 2016. Cash provided by investing activities for the nine months ended September 30, 2015 was $200 due to proceeds from the sale of tangible equipment.

There was no cash used in financing activities for the nine months ended September 30, 2016 or 2015.

Our MGP may withhold funds for future plugging and abandonment costs. Through September 30, 2016, our MGP has withheld $333,900 of funds for this purpose. Any additional funds, if required, will be obtained from production revenues or borrowings from our MGP or its affiliates, which are not contractually committed to make loans to us. The amount that we may borrow at any one time may not at any time exceed 5% of our total subscriptions, and we will not borrow from third-parties.

Critical Accounting Policies

See Note 2 to our condensed financial statements for additional information related to recently issued accounting standards.

For a more complete discussion of the accounting policies and estimates that we have identified as critical in the preparation of our condensed financial statements, please refer to our Management’s Discussion and Analysis of Financial Condition and Results of Operations in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2015~~2016.

ITEM 4.

CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Securities Exchange Act of 1934 reports is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our general partner’s Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure. In designing and evaluating the disclosure controls and procedures, our management recognized that any controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives, and our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible controls and procedures.

Under the supervision of our general partner’s Chief Executive Officer and Chief Financial Officer and with the participation of our disclosure committee appointed by such officers, we have carried out an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation, our general partner’s Chief Executive Officer and Chief Financial Officer concluded that, as of ~~September~~March 3031, ~~2016~~2017, our disclosure controls and procedures were effective at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There have been no changes in the Partnership’s internal control over financial reporting during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II OTHER INFORMATION

ITEM 1.

LEGAL PROCEEDINGS

The Partnership is a party to various routine legal proceedings arising out of the ordinary course of its business. Management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the Partnership’s financial condition or results of operations.

Affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising in the ordinary course of their respective businesses. The MGP’s management believes that none of these actions, individually or in the aggregate, will have a material adverse effect on the MGP’s financial condition or results of operations.

2017

ITEM 6.

EXHIBITS

EXHIBIT INDEX

Exhibit No.		Description
31.1		Certification Pursuant to Rule 13a-14/15(d)-14

31.2		Certification Pursuant to Rule 13a-14/15(d)-14

32.1		Section 1350 Certification

32.2		Section 1350 Certification

101		Interactive Data File

2118

SIGNATURES

Pursuant to the requirements of the Securities of the Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		ATLAS AMERICA PUBLIC #9 LTD.
	By:	Atlas Resources, LLC, its
		Managing General Partner
Date: November 21, 2016	By:	/s/ FREDDIE M. KOTEK
Date: May 15, 2017	By:	/s/ FREDRICK M. STOLERU
		Freddie M. Kotek, Chief Executive Officer and President of the Managing General Partner
		Fredrick M. Stoleru, Chairman of the Board and Chief Executive Officer (principal executive officer)

Date: November 21, 2016	By:	/s/ JEFFREY M. SLOTTERBACK
Date: May 15, 2017	By:	/s/ JEFFREY M. SLOTTERBACK
		Jeffrey M. Slotterback, Chief Financial Officer of the Managing General Partner

2219

Filing Compare · ATLAS AMERICA PUBLIC #9 LTD.