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 ~~March~~June 3130, 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~~Exact name of ~~small~~registrant ~~business~~as ~~issuer~~specified in its charter)

Pennsylvania		25-1867510
(State or other jurisdiction ofincorporation or organization)		(I.R.S. EmployerIdentification No.)
425 Houston Street, Suite 300
c/o DGOC Partnership Holdings, LLC 1100 Corporate Drive
Fort Worth, TX		76102
Birmingham, Alabama		76102
(Address of principal executive offices)		(zip code)

~~Issuer~~Registrant’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 an emerging growth company. See definitions of “large accelerated filer”, “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

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:	Financial Statements (Unaudited)
	Condensed Balance Sheets as of March 31, 2017 and December 31, 2016	3
	Condensed Balance Sheets as of June 30, 2017 and December 31, 2016	3
	Condensed Statements of Operations for the Three Months ended March 31, 2017 and 2016	4
	Condensed Statements of Operations for the Three and Six Months ended June 30, 2017 and 2016	4
	Condensed Statements of Comprehensive Loss for the Three Months ended March 31, 2017 and 2016	5
	Condensed Statements of Comprehensive Loss for the Three and Six Months ended June 30, 2017 and 2016	5
	Condensed Statement of Changes in Partners’ Deficit for the Three Months ended March 31, 2017	6
	Condensed Statement of Changes in Partners’ Deficit for the Six Months ended June 30, 2017	6
	Condensed Statements of Cash Flows for the Three Months ended March 31, 2017 and 2016	7
	Condensed Statements of Cash Flows for the Six Months ended June 30, 2017 and 2016	7
	Notes to Condensed Financial Statements	8
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1210
Item 4:	Controls and Procedures	1613
PART II	OTHER INFORMATION
Item 1:	Legal Proceedings	1714
Item 6:	Exhibits	1815
SIGNATURES		1916
CERTIFICATIONS

PART I. FINANCIAL INFORMATION

ITEM I FINANCIAL STATEMENTS

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED BALANCE SHEETS

(Unaudited)

	March 31,2017			December 31,2016
	June 30,2017			December 31,2016
ASSETS
Current assets:
Cash	$	-		$	-
Accounts receivable trade-affiliate		4340,~~900~~000			41,700
Total current assets		4340,~~900~~000			41,700
Gas and oil properties, net		338,500			338,500
Long-term asset retirement receivable-affiliate		~~431~~479,~~200~~700			382,500
Total assets	$	~~813~~858,~~600~~200		$	762,700
LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities:
Accounts payable trade-affiliate	$	~~797~~891,~~600~~200		$	718,100
Accrued liabilities		51,~~400~~900			11,600
Total current liabilities		~~803~~893,~~000~~100			729,700
Asset retirement obligations		1,~~966~~983,~~000~~800			1,948,300
Commitments and contingencies (Note 4)
Partners’ deficit:
Managing general partner’s deficit		(~~495~~517,~~100~~500	)		(480,800	)
Limited partners’ deficit (1,500 units)		(1,~~460~~501,~~300~~200	)		(1,434,500	)
Total partners’ deficit		(12,~~955~~018,~~400~~700	)		(1,915,300	)
Total liabilities and partners’ deficit	$	~~813~~858,~~600~~200		$	762,700

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months EndedMarch 31,
	Three Months EndedJune 30,						Six Months EndedJune 30,
	2017			2016			2017		2016
REVENUES
Natural gas and oil	$	8664,600		$	4152,~~600~~200		$	151,200	$	93,800
Gain on mark-to-market derivatives		-			2,300
Loss on mark-to-market derivatives		-			(2,400	)		-		(100)
Total revenues		8664,600			4349,~~900~~800			151,200		93,700
COSTS AND EXPENSES
Production		8081,~~600~~500			75104,~~100~~900			162,100		180,000
Accretion of asset retirement obligations		17,~~700~~800			17,~~100~~200			35,500		34,300
General and administrative		28,~~400~~600			2526,~~600~~800			57,000		52,400
Total costs and expenses		~~126~~127,~~700~~900			~~117~~148,~~800~~900			254,600		266,700
Net loss	$	(4063,~~100~~300)	)	$	(7399,~~900~~100	)	$	(103,400)	$	(173,000	)
Allocation of net loss:
Managing general partner	$	(1422,~~300~~400)	)	$	(2734,~~100~~300	)	$	(36,700)	$	(61,400	)
Limited partners	$	(2540,~~800~~900)	)	$	(4664,800	)	$	(66,700)	$	(111,600	)
Net loss per limited partnership unit	$	(1727)	)	$	(3143	)	$	(44)	$	(74	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS

(Unaudited)

	Three Months Ended							Six Months Ended
	March 31,
	June 30,							June 30,
	2017			~~2016~~	2016			2017		2016
Net loss	$	~~(40,100~~	(63,300)	$	~~(73,900~~$	)(99,100	)	$	(103,400)	$	(173,000	)
Other comprehensive loss:
Less: reclassification adjustment to net loss of mark-to-market gains on cash flow hedges		-			(200	)
Less: reclassification adjustment for realized gain of cash flow hedges in net loss			-			(200	)		-		(400	)
Total other comprehensive loss		-	-		~~(200~~	)(200	)		-		(400	)
Comprehensive loss	$	~~(40,100~~$	(63,300)	$	~~(74,100~~$	)(99,300	)	$	(103,400)	$	(173,400	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ DEFICIT

FOR THE ~~THREE~~SIX MONTHS ENDED

~~March~~June 3130, 2017

(Unaudited)

	ManagingGeneralPartner			LimitedPartners			Total
Balance at December 31, 2016	$	(480,800	)	$	(1,434,500	)	$	(1,915,300	)
Participation in revenues, costs and expenses:
Net production revenues		2,100			3,900			6,000
Net production expenses		(3,900	)		(7,000	)		(10,900	)
Accretion of asset retirement obligations		(612,~~300~~600	)		(1122,~~400~~900	)		(1735,~~700~~500	)
General and administrative		(1020,~~100~~200	)		(1836,~~300~~800	)		(2857,~~400~~000	)
Net loss		(1436,~~300~~700	)		(2566,~~800~~700	)		(40103,~~100~~400	)
Balance at March 31, 2017	$	(495,100	)	$	(1,460,300	)	$	(1,955,400	)
Balance at June 30, 2017	$	(517,500	)	$	(1,501,200	)	$	(2,018,700	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #9 LTD.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months EndedMarch 31,
	Six Months EndedJune 30,
	2017			2016
Cash flows used in operating activities:
Net loss	$	(40103,~~100~~400	)	$	(73173,~~900~~000	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Accretion of asset retirement obligations		17,700			17,100
Non-cash loss on derivative value		-			5,100
Accretion of asset retirement obligations		35,500			34,300
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable trade-affiliate		(2,200	)		4,700
Decrease (increase) in accounts receivable trade-affiliate		1,700			(1,700)
Increase in asset retirement receivable-affiliate		(4897,~~700~~200	)		(4897,~~600~~100	)
Increase in accounts payable trade-affiliate		79173,~~500~~100			95232,~~300~~100
(Decrease) increase in accrued liabilities		(69,~~200~~700	)		~~5,400~~300
Net cash provided by operating activities		-			-
Cash flows from investing activities:
Net cash provided by investing activities		-			-
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

~~March~~June 3130, 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~~previously served as ~~its~~our Managing General Partner and Operator (“Atlas Resources” or ~~the~~ “Previous 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 also sponsors and manages 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~~America ~~Group~~Public #9 LTD. (the “Partnership”) is a Pennsylvania limited partnership, formed on July 27, 2000 with DGOC Partnership Holdings, LLC serving as its Managing General Partner (“~~Atlas~~DGOC ~~Energy Group~~Holdings”; ~~OTCQX:~~or ~~ATLS~~the “MGP”) and certain affiliates of the MGP serving as our Operators. DGOC Holdings is aan ~~publicly~~indirect ~~traded~~subsidiary ~~company~~of ~~and~~Diversified ~~manages~~Gas & ~~Titan~~Oil, ~~and~~PLC (“Diversified”). Unless the ~~MGP~~context ~~through~~otherwise arequires, 2%references ~~preferred~~below ~~member~~to ~~interest~~“the Partnership,” in“we,” ~~Titan~~“us,” “our” and “our company”, refer to Atlas America Public #9 LTD.

~~The~~On ~~Partnership~~May ~~has~~4, ~~drilled~~2017, Titan entered into a definitive agreement to sell, among other conventional assets, its general and ~~currently~~limited ~~operates~~partnership ~~wells~~equity ~~located~~interest (“Equity Interest”) in ~~Pennsylvania~~the Partnership to Diversified (the “Purchase and ~~Ohio~~Sale Agreement” or “PSA”). WeThe ~~have~~transaction nowas ~~employees~~subject to customary closing conditions, had an effective date of April 1, 2017 and ~~rely~~closed on ~~our~~June ~~MGP~~30, ~~for~~2017. ~~management~~Upon closing the PSA, ~~which~~the Previous MGP’s Equity Interest in ~~turn,~~the ~~relies~~Partnership onwas ~~Atlas~~transferred ~~Energy~~to ~~Group~~DGOC ~~for~~Holdings ~~administrative~~and ~~services.~~DGOC Holdings was admitted as a substitute managing general partner of the Partnership.

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, LLC, Titan’s parent company, for administrative services through a Transition Services Agreement effective through December 31, 2017.

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 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.

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 continued to remain low in 2017. These lower commodity prices have negatively impacted the Partnership’s revenues, earnings and cash flows. Sustained low commodity prices ~~will~~ have had a material and adverse effect on the Partnership’s liquidity position, resulting in net operating losses since 2015. 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~~is continuing the efforts of the Previous MGP 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 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.

IfThe ~~the~~recent ~~Partnership~~significant isdeclines ~~not~~in ~~able~~commodity toprices ~~continue~~have aschallenged ~~a going concern,~~ the Partnership’s ~~will~~ability ~~liquidate. If~~to ~~the~~fund ~~Partnership’s~~its operations ~~are~~and ~~liquidated,~~may amake ~~valuation~~it ofuneconomical for the Partnership’s ~~assets~~to ~~and~~produce ~~liabilities~~its ~~would~~wells beuntil ~~determined~~they byare andepleted ~~independent~~as ~~expert in accordance with~~ the ~~partnership~~Partnership ~~agreement~~originally intended. ItAccordingly, isthese ~~possible~~conditions ~~that~~raise ~~based~~substantial ondoubt ~~such~~about ~~determination,~~ the Partnership’s ~~would~~ability ~~not be able~~ to ~~make~~continue ~~any~~as ~~liquidation~~a ~~distributions~~going ~~to its limited partners~~concern. ~~A liquidation could occur without any further contributions from or distributions to the limited partners.~~

~~The~~If ~~significant risks and uncertainties related to~~ the Partnership’s ~~ability~~is tonot ~~fund~~able ~~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~~may ~~and~~liquidate. If ~~to fund~~ the Partnership’s ~~obligations;~~operations ~~however~~are liquidated, ~~the~~a ~~uncertainties~~valuation of ~~Titan’s and~~ the ~~MGP~~Partnership’s ~~liquidity~~assets and ~~capital~~liabilities ~~resources~~would ~~(as~~be ~~further~~determined ~~described~~by ~~below)~~an ~~raise~~independent ~~substantial~~expert ~~doubt~~in ~~about~~accordance ~~Titan’s~~with ~~and~~ the ~~MGP’s~~partnership ~~ability~~agreement. toDepending ~~continue~~on asthe adetermined ~~going concern~~values, ~~which further raises substantial doubt about~~ the Partnership’s ~~ability~~may tohave ~~continue~~no asnet aassets ~~going~~from ~~concern.~~which ~~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 ita ~~uneconomical~~liquidation ~~for~~distribution ~~the Partnership~~ to ~~produce~~ its ~~wells~~limited ~~until they are depleted as originally intended~~partners. ~~The~~A ~~financial~~liquidation ~~statements~~could ~~have~~occur ~~been~~without 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~~further ~~that~~contributions ~~might result~~ from ~~the~~or ~~outcome~~distributions ~~of the going concern uncertainty. If the Partnership cannot continue as a going concern, adjustments~~ to the ~~carrying~~limited ~~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~~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 currently intends to continue the Partnership’s ~~Liquidity~~operations and to fund the Partnership’s obligations for at least the near term; however, ~~Capital~~the ~~Resources~~MGP’s bears no obligation to absorb the Partnership’s operating losses. Should the MGP cease to absorb these losses, the Partnership would likely be further impacted and ~~Ability~~may make it uneconomical for the Partnership to ~~Continue~~produce its wells until they are depleted as originally intended. The financial statements have been prepared on a ~~Going~~going ~~Concern~~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.

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.

Titan continually monitors the capital markets and the 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 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.

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.

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:

	March 31,2017			December 31,2016
	June 30,2017			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		(18,637,800	)		(18,637,800	)
Gas and oil properties, net	$	338,500		$	338,500

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 ~~March~~June 3130, 2017 and December 31, 2016 was entirely related to the estimated salvage value of such properties. The estimated salvage values were based on the MGP’s and the Previous MGP’s historical experience in determining such values.

Recently Issued Accounting Standards

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. We are evaluating the impact of this updated accounting guidance on our consolidated financial statements. This accounting guidance will require that our revenue recognition policy disclosures include further detail regarding our performance obligations as to the nature, amount, timing, and estimates of revenue and cash flows generated from our contracts with customers. We are still in the process of determining whether or not we will use the retrospective method or the modified retrospective approach to implementation.

accounting guidance on our condensed financial statements, expect to use the modified retrospective approach to implementation and do not expect the application of the revised standard to have a material impact on our financial statements and related disclosures.

NOTE 3 - 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 EndedMarch 31,
	Three Months EndedJune 30,				Six Months EndedJune 30,
	2017		2016		2017		2016
Administrative fees	$	13,~~500~~700	$	1113,~~600~~100	$	27,200	$	24,700
Supervision fees		6061,~~600~~700		5259,~~200~~000		122,300		111,200
Transportation fees		97,~~400~~900		56,~~700~~200		17,300		11,900
Direct costs		2526,~~500~~800		3153,~~200~~400		52,300		84,600
Total	$	~~109~~110,~~000~~100	$	~~100~~131,700	$	219,100	$	232,400

The MGP and its affiliates, with administrative support from the Previous MGP, perform all administrative and management functions for the Partnership, including billing revenues and paying expenses. Accounts payable trade-affiliate on the Partnership’s balance sheets includes the net production revenues due to the MGP.

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~~our ~~MGP,~~operators ~~as operator,~~ may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of ~~March~~June 3130, 2017, the ~~MGP~~operators ~~has~~have withheld $~~431~~479,~~200~~700 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~~This ~~used in this~~ Form 10-Q, includes “forward-looking statements” within the ~~words~~meaning of Section 27A of the Securities Act of 1933 (the “~~believes~~Securities Act”), ~~“anticipates~~as amended,” ~~“expects”~~ and ~~similar~~Section ~~expressions~~21E ~~are~~of ~~intended~~the toSecurities ~~identify~~Exchange ~~forward-looking~~Act ~~statements~~of 1934, as amended (the “Exchange Act”). ~~Such~~These statements ~~are~~involve ~~subject~~known toand ~~certain~~unknown risks, uncertainties and ~~uncertainties,~~other ~~which~~factors ~~could~~that may cause our actual results, performance or achievements to ~~differ~~be materially different from ~~the~~any future results, ~~stated~~performance or achievements expressed or implied by the forward-looking statements. In some cases, you can identify forward-looking statements in this ~~document~~Form 10-Q by words such as “anticipate,” “project,” “intend,” “estimate,” “expect,” “believe,” “predict,” “budget,” “projection,” “goal,” “plan,” “forecast,” “target” or similar expressions. 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.

We caution you that the forward-looking statements contained in this Form 10- Q are subject to all of the risks and uncertainties, many of which are beyond our control, incident to the production and sale of oil and natural gas. These risks include, but are not limited to, the risks described in our Annual Report on Form 10-K for the year ended December 31, 2016 (the “2016 Annual Report on Form 10-K”),including under the heading entitled “Forward-Looking Statements,” and all quarterly reports on Form 10-Q filed subsequently thereto. Should one or more of the risks or uncertainties described herein or in our 2016 Annual Report on Form 10-K occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. We specifically disclaim all responsibility to publicly update any information contained in a forward-looking statement or any forward-looking statement in its entirety and therefore disclaim any resulting liability for potentially related damages.

General

~~Atlas~~See ~~America~~Note ~~Public~~1 #9to ~~LTD.~~our ~~(“we”,~~condensed ~~“us”~~financial orstatements ~~the~~for ~~“Partnership”) is~~ a ~~Pennsylvania~~description 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~~our 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 also sponsors and manages 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~~our ofprevious ~~Atlas~~managing ~~Resource~~general ~~Partners,~~partner ~~L.P.~~ (“~~ARP~~Previous MGP”), ~~a Delaware limited partnership organized in 2012. Unless the context otherwise requires, references below to “the Partnership,” “we,” “us,” “our”~~ and ~~“our~~Appalachia ~~company”, refer to Atlas America Public #9 LTD~~Divestiture.

Atlas Energy Group, LLC (“Atlas Energy Group”; OTCQX: ATLS) is a publicly traded company and 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.

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 continued to remain low in 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 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 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 have continued to decline and 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, could negatively impact the MGP’s ability to remain in compliance with the covenants under its credit facilities.

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

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,~~operators ~~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 production and sale of oil, 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~~operators, ~~as operator,~~ may retain $200 per month, per well, to cover the estimated future plugging and abandonment costs of the well. As of ~~March~~June 3130, 2017, our ~~MGP~~operators ~~has~~have withheld $~~431~~479,~~200~~700 of net production revenues for this purpose.

Results of Operations

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

	Three Months EndedMarch 31,
	Three Months EndedJune 30,						Six Months EndedJune 30,
	2017			2016			2017			2016
Production revenues (in thousands):
Gas	$	7265		$	4243		$	137		$	85
Oil		15-			-9			15			9
Total	$	8765		$	4252		$	152		$	94
Production volumes:
Gas (mcf/day) (1)		~~259~~261			~~316~~348			259			332
Oil (bbl/day) (1)		4-			-2			2			1
Total (mcfe/day) (1)		~~283~~261			~~316~~360			271			338
Average sales prices: (2)
Gas (per mcf) (1)	$	32.0975		$	1.4538		$	2.92		$	1.41
Oil (per bbl) (1)	$	~~37.83~~-		$	-38.20		$	37.83		$	38.20
Production costs:
As a percent of revenues		93126	%		~~180~~201	%		107	%		192	%
Per mcfe (1)	$	3.1547		$	23.6117		$	3.30		$	2.91
Depletion per Mcfe(3)	$	-		$	-		$	-		$	-

(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 six mcfs to one bbl.

(2)	Average sales prices represent accrual basis pricing.

~~Natural Gas Revenues. Our natural gas revenues were $72,000 and $41,600 for the three months ended March 31, 2017 and 2016, respectively, an increase of $30,400~~ (~~73%~~3). ~~The~~Following ~~$30,400 increase in natural gas revenues for~~ the ~~three~~full ~~months~~impairment ~~ended~~of ~~March 31, 2017 as compared to~~ the ~~prior~~Partnership’s ~~year~~oil ~~similar~~and ~~period was attributable to a $38,300 increase in our natural~~ gas ~~sales~~properties ~~prices which were driven by market conditions, partially offset by a $7,900 decrease~~ in ~~production volumes. Our production volumes decreased to 259 mcf per day for the three months ended March 31~~2015, ~~2017 from 316 mcf per day for~~ the ~~three~~Partnership ~~months~~has ~~ended~~recognized ~~March~~no ~~31,~~depletion ~~2016, a decrease of 57 mcf per day (18%)~~expense. The overall decrease in natural gas production volumes for the three months ended March 31, 2017 as compared to the prior year similar period is due to the normal decline inherent in the life of a well.

~~Oil~~ Revenues. We drilled wells primarily to produce natural gas, rather than oil, but some wells have limited oil production. Our oil revenues were $14,600 for the three months ended March 31, 2017. Our production volumes were 4.28 bbls per day for the three months ended March 31, 2017.

15The following tables reconcile the changes in natural gas, oil and total revenue for the respective periods presented by reflecting the effect of changes in volume and in the underlying commodity prices.

Gain on Mark-to-Market Derivatives. We recognized changes in fair value of our derivatives immediately within (loss) gain on mark-to-market derivatives on our condensed statements of operations. As of December 31, 2016, all derivative contracts have matured and we have not entered into any new contracts.

	Three Months Ended June 30,
			Natural gas			Oil			Total
Revenues for the three months ended June 30, 2016		$	43,700		$	8,500		$	52,200
Volume decrease			(11,300	)		(8,500	)		(19,800	)
Price increase			32,200			-			32,200
Net increase (decrease)			20,900			(8,500	)		12,400
Revenues for the three months ended June 30, 2017		$	64,600		$	-		$	64,600

We 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.

	Six Months Ended June 30,
			Natural gas			Oil		Total
Revenues for the six months ended June 30, 2016		$	85,300		$	8,500	$	93,800
Volume (decrease) increase			(19,300	)		5,900		(13,400	)
Price increase			70,600			200		70,800
Net increase			51,300			6,100		57,400
Revenues for the six months ended June 30, 2017		$	136,600		$	14,600	$	151,200

~~Costs~~The ~~and~~natural ~~Expenses.~~gas ~~Production~~and ~~expenses~~oil ~~were~~volume ~~$80,600~~variances ~~and~~reflected ~~$75,100~~ for the ~~three~~periods ~~months~~presented ~~ended~~in ~~March~~the ~~31,~~tables ~~2017~~above ~~and~~relate ~~2016,~~to ~~respectively,~~(1) anwells ~~increase~~being oftemporarily $5shut-in,~~500~~ (7%2). ~~This~~which ~~increase~~may ~~was~~result ~~primarily~~in ~~due~~timing todifferences anassociated ~~increase~~with inthe ~~well~~production ~~supervision~~from ~~fees~~those ~~during~~wells ~~the~~depending ~~three~~upon ~~months~~when ~~ended~~they ~~March~~are 31placed back into production, ~~2017.~~and (3) normal and expected declines inherent in the life of a well.

~~General~~Gain ~~and~~on ~~administrative~~Mark-to-Market ~~expenses~~Derivatives. ~~for~~We ~~the~~recognized ~~three~~changes ~~months~~in ~~ended~~fair ~~March~~value of our derivatives immediately within (loss) gain on mark-to-market derivatives on our condensed statements of operations. As of December 31, ~~2017~~2016, all derivative contracts have settled and ~~2016~~we ~~were~~entered ~~$28,400~~into no new contracts. For the three and ~~$25~~six months ended June 30,~~600,~~ ~~respectively~~2016, anwe ~~increase~~recognized a loss on mark-to-market derivatives of $2,~~800~~400 ~~(11%).~~and ~~These~~$100, ~~expenses~~respectively. ~~include~~The ~~third~~mark-~~party~~to-market ~~costs~~change ~~for~~was ~~services~~primarily asdue ~~well~~to aschanges ~~the~~in ~~monthly~~natural ~~administrative~~gas ~~fees~~prices ~~charged~~during bythe ~~our MGP~~periods.

Costs and Expenses. Production expenses were $81,500 and $104,900 for the three months ended June 30, 2017 and 2016, respectively, a decrease of $23,400 (22%). Production expenses were $162,100 and $180,000 for the six months ended June 30, 2017 and 2016, respectively, a decrease of $17,900 (10%). This decrease was primarily due to a decrease in repairs and maintenance expenses during the three and six months ended June 30, 2017 when compared to the prior year similar period.

General and administrative expenses for the three months ended June 30, 2017 and 2016 were $28,600 and $26,800, respectively, an increase of $1,800 (7%). For the six months ended June 30, 2017 and 2016, the expenses were $57,000 and $52,400, respectively, and increase of $4,600 (9%). These expenses include third-party costs for services as well as the monthly administrative fees charged by our MGP.

Cash Flows Overview. There were no cash flows from operating activities for cash receipts and disbursements attributable to our normal monthly operating cycle for gas and oil production, lease operating expenses, gathering, processing and transportation expenses, severance taxes, general and administrative expenses.

There was no cash provided by investing activities for the three and six months ended ~~March~~June 3130, 2017 and 2016.

There was no cash used in financing activities for the three and six months ended ~~March~~June 3130, 2017 or 2016.

Our MGP may withhold funds for future plugging and abandonment costs. Through ~~March~~June 3130, 2017, our MGP has withheld $~~431~~479,~~200~~700 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.

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

See Note 1 to our condensed financial statements for additional information related to liquidity, capital resources and the ability to continue as a going concern.

As discussed in greater detail in Note 1 to our condensed financial statements, 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 currently intends to continue the Partnership’s operations and to fund the Partnership’s obligations; however, the MGP bears no obligation to absorb the Partnership’s operating losses. Should the MGP cease to absorb these losses, the Partnership would likely 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 liability and the reported amounts of income and expenses could be required and could be material.

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, 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~~Operating 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~~Operating Officer concluded that, as of ~~March~~June 3130, 2017, our disclosure controls and procedures were effective at the reasonable assurance level.

1613

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.

1714

ITEM 6.

EXHIBITS

EXHIBIT INDEX

Exhibit No.		Description
3.1		Amendment to Amended and Restated Certificate and Agreement of Limited Partnership of Atlas America Public #9 LTD dated June 30, 2017 (filed as Exhibit 3.1 to the Partnership’s Current Report on Form 8-K dated June 30, 2017 and incorporated herein by reference)
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

1815

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~~DGOC ~~Resources~~Partnership Holdings, LLC, its
		Managing General Partner
Date: May 15, 2017	By:	/s/ FREDRICK M. STOLERU
Date: August 11, 2017	By:	/s/ Robert R. Hutson, Jr.
		Fredrick M. Stoleru, Chairman of the Board and Chief Executive Officer (principal executive officer)
		Robert R. Hutson, Jr., Chief Executive Officer (principal executive officer) of the Managing General Partner

Date: May 15, 2017	By:	/s/ JEFFREY M. SLOTTERBACK
Date: August 11, 2017	By:	/s/ Bradley G. Gray
		Jeffrey M. Slotterback, Chief Financial Officer of the Managing General Partner
		Bradley G. Gray, Chief Operating Officer (principal financial officer) of the Managing General Partner

1916

Filing Compare · ATLAS AMERICA PUBLIC #9 LTD.