UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended ~~March~~June 3130, 2016

¨	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 000-50246

ATLAS AMERICA PUBLIC #11-2002 LTD.

(Name of small business issuer in its charter)

Delaware		02-0600231
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Park Place Corporate Center One 1000 Commerce Drive, 4th Floor 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 x 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 x No ¨

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

Large accelerated filer	¨	Accelerated filer	¨

Non-accelerated filer	¨	Smaller reporting company	x

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

ATLAS AMERICA PUBLIC #11-2002 LTD.

(A Delaware Limited Partnership)

INDEX TO QUARTERLY REPORT

ON FORM 10-Q

		PAGE
PART I.	FINANCIAL INFORMATION (Unaudited)
Item 1:
	Condensed Balance Sheets as of March 31, 2016 and December 31, 2015	3
	Condensed Balance Sheets as of June 30, 2016 and December 31, 2015	3
	Condensed Statements of Operations for the Three Months ended March 31, 2016 and 2015	4
	Condensed Statements of Operations for the Six Months ended June 30, 2016 and 2015	4
	Condensed Statements of Comprehensive Loss for the Three Months ended March 31, 2016 and 2015	5
	Condensed Statements of Comprehensive Loss for the Six Months ended June 30, 2016 and 2015	5
	Condensed Statement of Changes in Partners’ Deficit for the Three Months ended March 31, 2016	6
	Condensed Statement of Changes in Partners’ Deficit for the Six Months ended June 30, 2016	6
	Condensed Statements of Cash Flows for the Three Months ended March 31, 2016 and 2015	7
	Condensed Statements of Cash Flows for the Six Months ended June 30, 2016 and 2015	7
	Notes to Condensed Financial Statements	8
Item 2:	Management’s Discussion and Analysis of Financial Condition and Results of Operations	13
Item 4:	Controls and Procedures	1617
PART II.	OTHER INFORMATION
Item 1:	Legal Proceedings	17
Item 6:	Exhibits	18
SIGNATURES		19
CERTIFICATIONS

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ATLAS AMERICA PUBLIC #11-2002 LTD.

CONDENSED BALANCE SHEETS

(Unaudited)

	March 31,2016			December 31,2015
	June 30,2016			December 31,2015
ASSETS
Current assets:
Cash	$	-		$	-
Accounts receivable trade–affiliate		3847,~~800~~200			37,900
Current portion of derivative assets		167,500			19,900
Total current assets		5554,~~300~~700			57,800
Gas and oil properties, net		1,537,200			1,537,200
Long-term asset retirement receivable-affiliate		~~420~~519,700			321,700
Total assets	$	2,~~013~~111,~~200~~600		$	1,916,700
LIABILITIES AND PARTNERS’ DEFICIT
Current liabilities:
Accounts payable trade-affiliate	$	~~753~~958,~~000~~600		$	579,100
Accrued liabilities		1510,~~600~~900			10,100
Put premiums payable-affiliate		65,~~600~~100			9,200
Total current liabilities		~~775~~974,~~200~~600			598,400
Asset retirement obligations		4,~~162~~200,~~500~~200			4,124,800
Commitments and contingencies (Note 6)
Partners’ deficit:
Managing general partner’s deficit		(1,~~437~~485,~~700~~200)	)		(1,395,500	)
Limited partners’ deficit (3,126.55 units)		(1,~~487~~578,400)	)		(1,411,900	)
Accumulated other comprehensive income		~~600~~400			900
Total partners’ deficit		(23,~~924~~063,~~500~~200)	)		(2,806,500	)
Total liabilities and partners’ deficit	$	2,~~013~~111,~~200~~600		$	1,916,700

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #11-2002 LTD.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

		Three Months Ended
	Three Months EndedJune 30,								Six Months EndedJune 30,
		March 31,
	2016				2015				2016		2015
		2016				2015
REVENUES
REVENUES
Natural gas, oil and liquids	$	72,200			$	94,900			$	136,800	$	218,600
Natural gas, oil and liquids		$	64,600			$	123,700
(Loss) gain on mark-to-market derivatives		(2,500)				(2,300	)			400		200
Gain on mark-to-market derivatives			2,900				2,500
Total revenues		69,700				92,600				137,200		218,800
Total revenues			67,500				126,200
COSTS AND EXPENSES
COSTS AND EXPENSES
Production		132,500				128,500				246,800		290,500
Production			114,300				162,000
Depletion		-				4,500				-		8,100
Depletion			-				3,600
Accretion of asset retirement obligation		37,700				55,800				75,400		111,600
Accretion of asset retirement obligations			37,700				55,800
General and administrative		38,000				33,800				71,200		73,400
General and administrative			33,200				39,600
Total costs and expenses		208,200				222,600				393,400		483,600
Total costs and expenses			185,200				261,000
Net loss	$	(138,500)			$	(130,000	)		$	(256,200)	$	(264,800	)
Net loss		$	(117,700	)		$	(134,800	)
Allocation of net loss:
Allocation of net loss:
Managing general partner	$	(47,500)			$	(46,100	)		$	(89,700)	$	(95,100	)
Managing general partner		$	(42,200	)		$	(49,000	)
Limited partners	$	(91,000)			$	(83,900	)		$	(166,500)	$	(169,700	)
Limited partners		$	(75,500	)		$	(85,800	)
Net loss per limited partnership unit	$	(29)			$	(27	)		$	(53)	$	(54	)
Net loss per limited partnership unit		$	(24	)		$	(27	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #11-2002 LTD.

CONDENSED STATEMENTS OF COMPREHENSIVE LOSS

Unaudited)

		Three Months EndedMarch 31,
	Three Months EndedJune 30,								Six Months EndedJune 30,
	2016	~~2016~~			2015	~~2015~~			2016		2015
Net loss	$	$(138,500)	~~(117,700~~	)	$	$(130,000	~~(134,800~~)	)	$	(256,200)	$	(264,800	)
Other comprehensive loss:
Difference in estimated hedge receivable		-	-			1,100	~~1,600~~			-		2,700
Reclassification adjustment to net loss of mark-to-market gains on cash flow hedges		(500)	~~(300~~	)		(2,100	~~(2,300~~)	)		(500)		(4,400	)
Total other comprehensive loss		(500)	~~(300~~	)		(1,000	~~(700~~)	)		(500)		(1,700	)
Comprehensive loss	$	$(139,000)	~~(118,000~~	)	$	$(131,000	~~(135,500~~)	)	$	(256,700)	$	(266,500	)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #11-2002 LTD.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ DEFICIT

FOR THE ~~THREE~~SIX MONTHS ENDED

~~March~~June 3130, 2016

(Unaudited)

	ManagingGeneralPartner			LimitedPartners			Accumulated OtherComprehensiveIncome (Loss)			Total
Balance at December 31, 2015	$	(1,395,500	)	$	(1,411,900	)	$	900		$	(2,806,500	)
Participation in revenues, costs and expenses:
Net production expenses		(1738,400)	)		(3271,~~300~~600)	)		-			(49110,~~700~~000)	)
Gain on mark-to-market derivatives		-			~~2,900~~400			-			~~2,900~~400
Accretion of asset retirement obligations		(1326,~~200~~400)	)		(2449,~~500~~000)	)		-			(3775,~~700~~400)	)
General and administrative		(1124,~~600~~900)	)		(2146,~~600~~300)	)		-			(3371,200)	)
Net loss		(4289,~~200~~700)	)		(75166,500)	)		-			(~~117~~256,~~700~~200)	)
Other comprehensive loss		-			-			(~~300~~500)	)		(~~300~~500)	)
Balance at March 31, 2016	$	(1,437,700	)	$	(1,487,400	)	$	600		$	(2,924,500	)
Balance at June 30, 2016	$	(1,485,200)		$	(1,578,400)		$	400		$	(3,063,200)

See accompanying notes to condensed financial statements.

ATLAS AMERICA PUBLIC #11-2002 LTD.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months EndedMarch 31,
	Six months EndedJune 30,
	2016			2015
Cash flows from operating activities:
Net loss	$	(~~117~~256,~~700~~200)	)	$	(~~134~~264,800	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion		-			38,~~600~~100
Non-cash loss (gain) on derivative value, net		~~500~~7,800			(31,~~300~~900	)
Accretion of asset retirement obligations		3775,~~700~~400			55111,~~800~~600
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable trade-affiliate		(~~900~~9,300)	)		7423,~~800~~300
Increase in asset retirement receivable-affiliate		(99198,000)	)		-(99,000	)
Increase in accounts payable trade-affiliate		~~173~~379,~~900~~500			1227,~~300~~200
Increase in accrued liabilities		5,500			2,600
Increase (decrease) in accrued liabilities		800			(4,500	)
Net cash provided by operating activities		-			-
Cash flows from investing activities:
Net cash used in 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 #11 LTD.

NOTES TO CONDENSED FINANCIAL STATEMENTS

~~March~~June 3130, 2016

(Unaudited)

NOTE 1 - DESCRIPTION OF BUSINESS

Atlas America Public #11-2002 LTD. (the “Partnership”) is a Delaware limited partnership, formed on June 5, 2002 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Atlas Resource Partners, L.P. (“ARP”) (~~NYSE~~OTC: ~~ARP~~ARPJ). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas America Public #11-2002 LTD.

Atlas Energy Group, LLC (“Atlas Energy Group”; ~~OTCQX~~OTC: ATLS) manages ARP’s operations and activities through its ownership of ARP’s general partner interest.

The Partnership has drilled and currently operates wells located in Pennsylvania and Ohio. The Partnership has no employees and relies on the MGP for management, which in turn, relies on its parent company, Atlas Energy Group, for administrative services.

The Partnership’s operating cash flows are generated from its wells, which produce natural gas, oil and NGL. Produced natural gas, oil and NGL 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 six months ended June 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, oil and NGL will be sold are uncertain and the Partnership is not guaranteed a specific price for the sale of its production. Changes in natural gas, oil and NGL prices have a significant impact on the Partnership’s cash flow and the value of its reserves. Lower natural gas, oil and NGL prices may not only decrease the Partnership’s revenues, but also may reduce the amount of natural gas, oil and NGL that the Partnership can produce economically.

Liquidity and Capital Resources

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 MGP’s decision to liquidate the Partnership’s operations.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact the Partnership’s outlook. The Partnership has experienced downward revisions of its natural gas and oil reserves volumes and values due to the significant 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 opportunistic and aggressive 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 MGP’s decision to liquidate 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, the MGP determined that there is substantial doubt about the Partnership’s ability to continue as a going concern. The MGP intends, as necessary, to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to the Partnership’s ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

ARP’s revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices and recent conversations with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016. If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of the Partnership’s assets and liabilities would be determined by an independent expert. It is possible that based on such determination, we would not be able to make any liquidation distributions to our limited partners. A liquidation could result in the transfer of the post-liquidation assets and liabilities of the Partnership to the MGP and would occur without any further contributions from or distributions to the limited partners.

~~The~~Historically, ~~condensed~~there ~~financial~~has ~~statements,~~been ~~which~~no ~~are~~need ~~unaudited,~~to ~~except~~borrow ~~for~~funds from the ~~balance~~MGP ~~sheet~~to atfund ~~December~~operations ~~31,~~as ~~2015,~~the ~~which~~cash isflow ~~derived~~ from ~~audited~~the ~~financial~~Partnership’s ~~statements,~~operations have been ~~prepared~~adequate ~~pursuant~~ to ~~the~~fund ~~rules~~its obligations and ~~regulations~~distributions ofto ~~the~~its ~~Securities~~partners. ~~and~~However, ~~Exchange~~the ~~Commission~~recent ~~and~~significant ~~accounting~~declines ~~principles generally accepted~~ in ~~the~~commodity ~~United~~prices ~~States~~have ofchallenged ~~America~~the ~~(“U.S.~~Partnership’s ~~GAAP”)~~ability ~~for~~to ~~interim~~fund ~~reporting.~~its ~~Certain~~operations ~~information~~ and ~~note~~may ~~disclosures~~make ~~normally~~it ~~included~~uneconomical infor ~~annual~~the ~~financial~~Partnership ~~statements~~to ~~prepared~~produce inits ~~accordance~~wells ~~with~~until ~~U.S.~~they ~~GAAP~~are ~~have~~depleted ~~been~~as ~~condensed~~the orPartnership ~~omitted~~originally ~~pursuant~~intended. toAccordingly, ~~those~~the ~~rules~~MGP ~~and~~determined ~~regulations,~~that ~~although~~there weis ~~believe~~substantial ~~that~~doubt about the ~~disclosures~~Partnership’s ~~made~~ability ~~are adequate~~ to ~~make~~continue ~~the~~as ~~information~~a ~~not~~going ~~misleading~~concern. ~~These~~The ~~interim~~MGP ~~financial~~intends, ~~statements~~as ~~should~~necessary, beto ~~read~~continue ~~in conjunction with~~ the ~~audited~~Partnership’s ~~financial~~operations ~~statements~~ and ~~notes~~to ~~thereto~~fund ~~presented in~~ the Partnership’s ~~Annual~~obligations ~~Report~~for onat ~~Form~~least ~~10-K~~the ~~for~~next twelve months. To the ~~year~~extent ~~ended~~commodity ~~December~~prices ~~31,~~remain ~~2015.~~low ~~The~~or ~~results~~decline offurther ~~operations~~or ~~for~~ARP ~~the~~is ~~three~~unsuccessful ~~months~~in ~~ended~~completing ~~March~~its ~~31,~~Restructuring ~~2016~~(as ~~may~~defined ~~not~~below) ~~necessarily~~or bethe ~~indicative~~Plan of(as defined below), the ~~results~~MGP’s ofability ~~operations~~to ~~for~~continue the ~~year~~Partnership’s ~~ended~~operations ~~December 31,~~may ~~2016~~be further impacted.

ARP Restructuring and Chapter 11 Bankruptcy Proceedings

On July 25, 2016, 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 will reduce debt on its balance sheet (the “Restructuring”) pursuant to a pre-packaged plan of reorganization (the “Plan”). The Plan will position ARP for the future and is expected to be completed before the end of the third quarter of 2016, after which ARP should emerge from Chapter 11 (as defined below), backed by its stakeholders, committed to investing capital to develop its exploration and production assets, as well as its tax-advantaged drilling partnership program.

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 are being jointly administered under the caption “In re: ATLAS RESOURCE PARTNERS, L.P., et al.” Interested parties should refer to the information and the limitations and qualifications discussed in the disclosure statement related to the Restructuring which was filed as Exhibit 99.1 to ARP’s Current Report on Form 8-K filed with the Securities and Exchange Commission on July 25, 2016.

The MGP intends to continue to operate 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, it is contemplated that all suppliers, vendors, employees, royalty owners, trade partners and landlords will be unimpaired and will be satisfied in full in the ordinary course of business, and the MGP’s existing trade contracts and terms will be maintained. To assure ordinary course operations, 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 is not a party to the Restructuring Support Agreement. The ARP Restructuring is not expected to 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 will 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 is 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 is not expected to have a material impact on the ability of Atlas Energy Group management to operate ARP or the other Atlas Energy Group businesses.

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~~may differ from those estimates.

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. Differences between estimated and actual amounts are recorded in the following months’ financial results. Management believes that the operating results presented for the three months ended March 31, 2016 and 2015 represent actual results in all material respects.

Gas and Oil Properties

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

	March 31,2016			December 31,2015
	June 30,2016			December 31,2015
Proved properties:
Leasehold interests	$	695,700		$	695,700
Wells and related equipment		41,887,000			41,887,000
Total natural gas and oil properties		42,582,700			42,582,700
Accumulated depletion and impairment		(41,045,500)	)		(41,045,500	)
Gas and oil properties, net	$	1,537,200		$	1,537,200

As a result of the recent significant declines in commodity prices and associated recorded impairment charges, the remaining net book value of gas and oil properties on our condensed balance sheet at ~~March~~June 3130, 2016 and December 31, 2015 was primarily 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 August 2014, the FASB updated the accounting guidance related to the evaluation of whether there is substantial doubt about an entity’s ability to continue as a going concern. The updated accounting guidance requires an entity’s management to evaluate whether there are conditions or events that raise substantial doubt about its ability to continue as a going concern within one year from the date the financial statements are issued and provide footnote disclosures, if necessary. The updated guidance is effective as of January 1, 2017 and the Partnership is currently in the process of determining the impact of providing the enhanced disclosures, as applicable, within its condensed financial statements.

In May 2014, the FASB updated the accounting guidance related to revenue recognition. The updated accounting guidance provides a single, contract-based revenue recognition model to help improve financial reporting by providing clearer guidance on when an entity should recognize revenue, and by reducing the number of standards to which an entity has to refer. In July 2015, the FASB voted to defer the effective date by one year to December 15, 2017 for annual reporting periods beginning after that date. The updated accounting guidance provides companies with alternative methods of adoption. The Partnership is currently in the process of determining the impact that the updated accounting guidance will have on its condensed financial statements and its method of adoption.

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 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~~enters ~~net~~into ~~derivative~~commodity ~~assets~~put oncontracts ~~its~~to ~~balance~~achieve ~~sheets~~more ofpredictable ~~$16,500~~cash ~~and~~flows ~~$19,900~~by athedging ~~March~~the 31Partnership’s exposure to changes in commodity prices. At any point in time, ~~2016~~such contracts may include regulated New York Mercantile Stock Exchange (“NYMEX”) futures and ~~December~~options ~~31,~~contracts ~~2015~~and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, ~~respectively~~but may be settled by the physical delivery of the commodity. These contracts have been recorded at their fair values.

The ~~following~~Partnership ~~table~~reflected ~~summarizes~~net ~~the~~derivative ~~gains~~assets oron ~~losses~~its ~~recognized~~condensed ~~within~~balance ~~the~~sheets ~~statements~~ of ~~operations~~$7,500 ~~for~~and ~~derivative~~$19,900 ~~instruments~~at ~~previously~~June ~~designated~~30, as2016 ~~cash~~and ~~flow~~December ~~hedges~~31, ~~for~~2015, ~~the~~respectively. ~~periods indicated:~~

	Three Months Ended
	March 31,
	2016		2015
Gains reclassified from accumulated other comprehensive income into natural gas, oil and liquids revenues	$	300	$	2,300
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$	2,900	$	2,500

The following table summarizes the commodity derivative activity and presentation in the condensed statements of operations for the periods indicated:

At March 31, 2016, the Partnership had the following commodity derivatives:

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016		2015
Gains reclassified from accumulated other comprehensive income into natural gas, oil and liquids revenues	$	200	$	2,100		$	500	$	4,400
Gains subsequent to hedge accounting recognized in gain on mark-to-market derivatives	$	(2,500)	$	(2,300	)	$	400	$	200

At June 30, 2016, the Partnership had the following commodity derivatives:

Natural Gas Put Options

ProductionPeriod EndingDecember 31,	Volumes (3)	AverageFixed Price		Fair ValueAsset (2)
	(MMBtu) (1)		(per MMBtu)(1)
2016	86,600	$	4.15	$	167,500

(1)	“MMBtu” represents million British Thermal Units.

(2)	Fair value based on forward NYMEX natural gas prices, as applicable.

As(3) ~~the~~The ~~underlying~~production ~~prices~~volume ~~and~~for ~~terms~~2016 ininclude the ~~Partnership’s~~remaining ~~derivative~~six ~~contracts were consistent with the indices used to sell its natural gas and oil, there were no gains or losses recognized during the three~~ months ~~ended~~of ~~March 31,~~ 2016 ~~and~~beginning ~~2015~~July ~~for~~1, ~~hedge ineffectiveness~~2016.

As the underlying prices and terms in the Partnership’s derivative contracts were consistent with the indices used to sell its natural gas and oil, there were no gains or losses recognized during the three and six months ended June 30, 2016 and 2015 for hedge ineffectiveness.

NOTE 4 - FAIR VALUE OF FINANCIAL INSTRUMENTS

The Partnership uses a market approach fair value methodology to value ~~the assets and liabilities for~~ its outstanding derivative contracts. 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 ~~March~~June 3130, 2016 and December 31, 2015, all derivative financial instruments were classified as Level 2.

Information for assets measured at fair value at ~~March~~June 3130, 2016 and December 31, 2015 was as follows:

	Level 1		Level 2		Level 3		Total
As of March 31, 2016
As of June 30, 2016
Derivative assets, gross
Commodity puts	$	-	$	167,500	$	-	$	167,500

	Level 1		Level 2		Level 3		Total
As of December 31, 2015
Derivative assets, gross
Commodity puts	$	-	$	19,900	$	-	$	19,900

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 $320 per well per month for operating and maintaining the wells. Well supervision fees are proportionately reduced to the extent the Partnership does not acquire 100% of the working interest in a well. Transportation fees are included in production expenses in the Partnership’s condensed statements of operations and are generally payable at 13% of the natural gas sales price. Direct costs, which are included in production and general administrative expenses in the Partnership’s condensed statements of operations, are payable to the MGP and its affiliates as reimbursement for all costs expended on the Partnership’s behalf.

The following table provides information with respect to these costs and the periods incurred:

		Three Months Ended March 31,
	Three Months Ended June 30,						Six Months Ended June 30,
	2016	~~2016~~		2015	~~2015~~		2016		2015
Administrative fees	$	$24,200	~~19,400~~	$	$19,800	~~25,300~~	$	43,600	$	45,100
Supervision fees		103,300	~~82,800~~		84,400	~~108,100~~		186,100		192,500
Transportation fees		8,000	~~7,500~~		7,100	~~14,400~~		15,500		21,500
Direct costs		35,000	~~37,800~~		51,000	~~53,800~~		72,800		104,800
Total	$	$170,500	~~147,500~~	$	$162,300	~~201,600~~	$	318,000	$	363,900

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 ~~expense~~expenses due to the MGP.

NOTE 6 - COMMITMENTS AND CONTINGENCIES

General Commitments

Subject to certain conditions, investor partners may present their interests for purchase by the MGP. The purchase price is calculated by the MGP in accordance with the terms of the Partnership agreement. The MGP is not obligated to purchase more than 5% of the total outstanding units in any calendar year. In the event that the MGP is unable to obtain the necessary funds, it may suspend its purchase obligation.

Beginning one year after each of the Partnership’s wells has been placed into production, the MGP, as operator, may retain $200 per month per well to cover estimated future plugging and abandonment costs. As of March 31, 2016, the MGP withheld $420,700 of net production revenue for future plugging and abandonment costs.

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.

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 June 30, 2016, the MGP withheld $519,700 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. Management and MGP’s management believe 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 #11-2002 LTD. (“we”, “us”, or the “Partnership”) is a Delaware limited partnership, formed on June 5, 2002 with Atlas Resources, LLC serving as its Managing General Partner and Operator (“Atlas Resources” or the “MGP”). Atlas Resources is an indirect subsidiary of Atlas Resource Partners, L.P. (“ARP”) (~~NYSE~~OTCQX: ~~ARP~~ARPJ). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas America Public #11-2002 LTD.

Atlas Energy Group, LLC (“Atlas Energy Group”) manages ARP’s operations and activities through its ownership of the ARP’s general partner interest.

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 its parent company, Atlas Energy Group, for administrative services.

We intend to continue to produce our wells until they are depleted or become uneconomical to produce, at which time they will be plugged and abandoned or sold. We expect that no other wells will be drilled and no additional funds will be required for drilling.

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 ~~March~~June 3130, 2016, our MGP withheld $~~420~~519,700 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, production costs and depletion during the periods indicated:

		Three Months EndedMarch 31,
	Three Months EndedJune 30,								Six Months EndedJune 30,
	2016	~~2016~~			2015	~~2015~~			2016			2015
Production revenues (in thousands):
Gas	$	$64	58		$	$67	~~116~~		$	121		$	182
Oil		8	6			28	7			15			35
Liquids		-	1			-	1			1			1
Total	$	$72	65		$	$95	~~124~~		$	137		$	219
Production volumes:
Gas (mcf/day) (1)		523	~~455~~			513	~~557~~			489			535
Oil (bbl/day) (1)		2	2			6	2			2			4
Liquids (bbl/day) (1)		-	-			-	-			-			-
Total (mcfe/day) (1)		535	~~467~~			549	~~569~~			501			559
Average sales prices: (2)
Gas (per mcf) (1)	$	$1.33	~~1.39~~		$	$1.42	~~2.54~~		$	1.36		$	1.88
Oil (per bbl)	$	$42.94	~~31.34~~		$	$54.38	~~43.85~~		$	37.00		$	51.90
Liquids (per bbl) (1)	$	$13.32	~~18.73~~		$	$-	~~35.61~~		$	16.92		$	31.87
Production costs:
As a percent of revenues		184	~~177~~%	%		136	~~131~~%	%		180	%		133	%
Per mcfe (1)	$	$2.71	~~2.67~~		$	$2.58	~~3.16~~		$	2.69		$	2.87
Depletion per mcfe	$	$-	-		$	$0.09	~~0.07~~		$	-		$	0.08

(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 $5763,600 and $~~115~~66,~~800~~500 for the three months ended ~~March 31~~June 30, 2016 and 2015, respectively, a decrease of $582,~~200~~900 (504%). The $582,~~200~~900 decrease in natural gas revenues for the three months ended ~~March 31~~June 30, 2016 as compared to the prior year similar period was attributable to a $384,300 decrease in our natural gas sales prices after the effect of financial hedges, which were driven by market conditions, ~~and~~partially offset by a $191,~~900~~400 ~~decrease~~increase in production volumes. Our production volumes ~~decreased~~increased to ~~455~~523 mcf per day for the three months ended ~~March 31~~June 30, 2016 from ~~557~~513 mcf per day for the three months ended ~~March~~June 3130, 2015, aan ~~decrease~~increase of ~~102~~10 mcf per day (182%). The decrease in production volumes is mostly due to the normal decline inherent in the life of the wells in addition to wells shut-in due to it being uneconomical to continue production in the current pricing environment.

~~Oil~~Our ~~Revenues. We drilled wells primarily to produce~~ natural gas, ~~rather than oil, but some wells have limited oil production. Our oil~~ revenues were $6121,~~500~~100 and $7182,~~000~~400 for the ~~three~~six months ended ~~March 31~~June 30, 2016 and 2015, respectively, a decrease of $~~500~~61,300 (734%). The $~~500~~61,300 decrease in ~~oil~~natural gas revenues for the ~~three~~six months ended ~~March 31~~June 30, 2016 as compared to the prior year similar period was attributable to a $246,~~600~~700 decrease in ~~oil~~our natural gas sales prices after the effect of financial hedges, ~~partially~~which ~~offset~~were driven by market conditions, and a $214,~~100~~600 ~~increase~~decrease in production volumes. Our production volumes ~~increased~~decreased to ~~2.27~~489 ~~bbls~~mcf per day for the ~~three~~six months ended ~~March 31~~June 30, 2016 from ~~1.76~~535 ~~bbls~~mcf per day for the ~~three~~six months ended ~~March~~June 3130, 2015, ana ~~increase~~decrease of ~~0.51~~46 ~~bbls~~mcf per day (299%). The decrease in production volumes is mostly due to the normal decline inherent in the life of the wells in addition to wells shut-in due to it being uneconomical to continue production in the current pricing environment.

~~Natural~~Oil ~~Gas Liquids Revenue~~Revenues. ~~The~~We ~~majority~~drill ofwells ~~our~~primarily ~~wells~~to produce ~~“dry~~natural gas”, ~~which~~rather isthan ~~composed~~oil, ~~primarily~~but ofsome ~~methane~~wells ~~and~~have ~~requires~~limited nooil ~~additional~~production. ~~processing~~Our ~~before~~oil ~~being~~revenues ~~transported~~were $8,500 and ~~sold~~$28,100 tofor the ~~purchaser.~~three ~~Some~~months ~~wells~~ended June 30, ~~however~~2016 and 2015, ~~produce~~respectively, ~~“wet~~a ~~gas”~~decrease of $19,600 ~~which~~(70%). ~~contains~~The ~~larger~~$19,600 ~~amounts~~decrease ofin ~~ethane~~oil ~~and~~revenues ~~other~~for ~~associated~~the ~~hydrocarbons~~three ~~(i.e.~~months ~~“natural~~ended ~~gas~~June 30, ~~liquids”)~~2016 ~~that~~as ~~must~~compared beto ~~removed~~the prior toyear ~~transporting~~similar ~~the~~period ~~gas.~~was ~~Once~~attributable ~~removed~~to a $17,300 ~~these~~decrease ~~natural~~in ~~gas~~production ~~liquids~~volumes ~~are~~and ~~sold~~a to$2,300 ~~various~~decrease ~~purchasers~~in oil prices. Our ~~natural~~production ~~gas~~volumes ~~liquids~~decreased ~~revenues~~to ~~were~~2.17 ~~$500~~bbls ~~and~~per ~~$900~~day for the three months ended ~~March 31~~June 30, 2016 ~~and~~from ~~2015, respectively~~5.67 ~~Our production volumes were 0.32 and 0.29~~ bbls per day for the three months ended ~~March~~June 30, 312015, ~~2016~~a ~~and~~decrease ~~2015,~~of ~~respectively~~3.5 bbls per day (62%).

~~Gain~~Our onoil ~~Mark-to-Market~~revenues ~~Derivatives.~~were On$15,000 ~~January~~and 1$35,000 ~~2015~~for the six months ended June 30, we2016 ~~discontinued~~and ~~hedge~~2015, ~~accounting~~respectively, ~~for~~a ~~our~~decrease ~~qualified~~of ~~commodity~~$20,000 ~~derivatives~~(57%). AsThe ~~such~~$20,000 ~~subsequent~~decrease ~~changes~~ in ~~fair~~oil ~~value~~revenues offor ~~these~~the ~~derivatives~~six ~~are~~months ~~recognized~~ended ~~immediately~~June 30, ~~within~~2016 ~~gain~~as oncompared ~~mark-~~to~~-market~~ ~~derivatives~~the onprior ~~our~~year ~~statements~~similar ofperiod ~~operations.~~was ~~The~~attributable ~~fair~~to ~~values~~a of$14,000 ~~these~~decrease ~~commodity~~in ~~derivative~~production ~~instruments~~volumes asand ofa ~~December 31~~$6,000 ~~2014,~~decrease ~~which~~in ~~were~~oil ~~recognized~~prices. inOur ~~accumulated~~production ~~other~~volumes ~~comprehensive~~decreased ~~income~~to ~~within~~2.22 ~~partners’~~bbls ~~capital~~per onday ~~our~~for ~~balance~~the ~~sheet,~~six ~~will~~months beended ~~reclassified~~June 30, to2016 ~~our~~from ~~statements~~3.73 ofbbls ~~operations~~per inday for the ~~future~~six atmonths ~~the~~ended ~~time~~June 30, ~~the~~2015, ~~originally~~a ~~hedged~~decrease ~~physical~~of ~~transactions~~1.5 ~~settle~~bbls per day (40%).

WeNatural ~~recognized~~Gas aLiquids ~~gain~~Revenue. onThe ~~mark-~~majority of our wells produce “dry gas”, which is composed primarily of methane and requires no additional processing before being transported and sold to~~-market~~ ~~derivatives~~the purchaser. Some wells, however, produce “wet gas”, which contains larger amounts of $2ethane and other associated hydrocarbons (i.e. “natural gas liquids”) that must be removed prior to transporting the gas. Once removed,~~900~~ these natural gas liquids are sold to various purchasers. Our natural gas liquids revenues were $100 and $~~2,500~~300 for the ~~periods~~three months ended ~~March 31~~June 30, 2016 and 2015, respectively. ~~These~~Our ~~gains~~natural ~~were~~gas ~~due~~liquids torevenues ~~mark-to-market~~were ~~gains~~$700 ~~primarily~~and ~~related~~$1,200 tofor the ~~change~~six inmonths ~~natural~~ended ~~gas~~June 30, ~~prices~~2016 ~~during~~and ~~the~~2015, ~~periods~~respectively.

~~Costs~~Gain ~~and~~on ~~Expenses~~Mark-to-Market Derivatives. ~~Production~~We ~~expenses~~recognize ~~were~~changes ~~$114,300~~in ~~and~~fair ~~$162,000~~value ~~for the three months ended March 31, 2016 and 2015, respectively, a decrease~~ of ~~$47,700~~our ~~(29%).~~derivatives ~~This~~immediately ~~decrease~~within ~~was~~gain ~~mostly~~on ~~attributable~~ mark-to-market aderivatives ~~decrease~~on inour ~~supervision~~condensed ~~fees~~statements ~~due~~of ~~to wells being shut-in and a decrease in transportation~~operations.

~~For~~We ~~the~~recognized ~~three~~a ~~months~~loss ~~ended~~on ~~March~~mark-to-market ~~31,~~derivatives ~~2016~~of $2,500 ~~there~~and ~~was~~$2,300 nofor ~~depletion recorded due to~~ the ~~recent~~three ~~significant~~months ~~declines~~ended inJune ~~commodity~~30, ~~prices~~2016 and ~~associated~~2015, ~~recorded impairment charges. Therefore~~respectively, ~~the~~and ~~remaining~~a ~~net~~gain ~~book value~~ of ~~gas~~$400 and ~~oil~~$200 ~~properties~~for onthe ~~our~~six ~~balance~~months ~~sheet~~ended atJune ~~December 31~~30, ~~2015~~2016 ~~was~~and ~~primarily~~2015, ~~related to the estimated salvage value of such properties~~respectively. ~~For~~ ~~the~~These ~~three~~losses ~~months~~were ~~ended~~due ~~March~~to ~~31,~~mark-to-market ~~2015,~~losses ~~depletion~~primarily ofrelated ~~gas~~to ~~and~~the ~~oil~~change ~~properties~~in asnatural ~~a percentage of~~ gas ~~and~~prices ~~oil~~during ~~revenues~~the ~~was 3%~~periods.

~~General~~Costs and ~~administrative~~Expenses. Production expenses were $132,500 and $128,500 for the three months ended ~~March~~June 3130, 2016 and 2015 ~~were $33~~,~~200~~ ~~and $39,600,~~ respectively, aan ~~decrease~~increase of $64,~~400~~000 (163%). Production ~~These~~ expenses ~~include~~were ~~third-party~~$246,800 ~~costs~~and $290,500 for ~~services~~the assix ~~well~~months asended ~~the~~June ~~monthly~~30, ~~administrative~~2016 ~~fees~~and ~~charged~~2015, byrespectively, ~~our~~a ~~MGP~~decrease ~~and~~of ~~vary~~$43,700 ~~from~~(15%). ~~period~~This todecrease ~~period~~was ~~due~~mostly attributable to ~~the~~a ~~costs~~decrease ~~charged~~in supervision fees due to uswells being shut-in and ~~services~~a ~~provided~~decrease toin ustransportation.

~~Liquidity~~For the six months ended June 30, 2016, there was no depletion recorded due to the recent significant declines in commodity prices and ~~Capital~~associated ~~Resources~~previously recorded impairment charges. Therefore, the remaining net book value of gas and oil properties on our balance sheet at December 31, 2015 was primarily related to the estimated salvage value of such properties. For the six months ended June 30, 2015, depletion of gas and oil properties as a percentage of gas and oil revenues was 3%.

WeGeneral ~~are~~and ~~generally~~administrative ~~limited~~expenses tofor the ~~amount~~three months ended June 30, 2016 and 2015 were $38,000 and $33,800, respectively, an increase of ~~funds~~$4,200 ~~generated~~(12%). byFor the ~~cash~~six ~~flows~~months ~~from~~ended ~~our~~June 30, ~~operations~~2016 and 2015, ~~which~~these weexpenses ~~believe~~were is$71,200 ~~adequate~~and to$73,400, ~~fund~~respectively, ~~future~~a ~~operations~~decrease ~~and~~of ~~distributions~~$2,200 to(3%). These expenses include third-party costs for services as well as the monthly administrative fees charged by our ~~partners~~MGP. ~~Historically~~The increase for the three months ended June 30, ~~there~~2016 ~~has~~was ~~been~~primarily nodue ~~need~~to third-party costs as compared to ~~borrow~~the ~~funds~~prior ~~from~~year ~~our~~similar ~~MGP~~period. The decrease for the six months ended June 30, 2016 was primarily due to ~~fund~~was ~~operations.~~primarily due to third-party costs as compared to the prior year similar period.

The natural gas, oil and natural gas liquids commodity price markets have suffered significant declines throughout 2015 and have continued to decline and remain low in 2016. The extreme ongoing volatility in the energy industry and commodity prices will likely continue to impact our outlook. We have experienced downward revisions of its natural gas and oil reserves volumes and values due to the significant declines in commodity prices. Our MGP continues to implement various cost saving measures to reduce our 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. Our MGP will continue to be opportunistic and aggressive in managing our cost structure and, in turn, liquidity to meet our operating needs. To the extent commodity prices remain low or decline further, or we experience other disruptions in the industry, our ability to fund our operations and make distributions may be further impacted, and could result in the MGP’s decision to liquidate our operations.

Historically, there has been no need to borrow funds from the MGP to fund operations as the cash flow from our operations have been adequate to fund our obligations and distributions to our partners. However, the recent significant declines in commodity prices have challenged our ability to fund our operations and may make it uneconomical to produce our wells until they are depleted as we originally intended. Accordingly, the MGP determined that there is substantial doubt about our ability to continue as a going concern. The MGP intends, as necessary, to continue our operations and to fund our obligations for at least the next twelve months. The MGP has concluded that such undertaking is sufficient to alleviate the doubt as to our ability to continue as a going concern. To the extent commodity prices remain low or decline further, ARP experiences disruptions in the financial markets impacting its respective longer-term access to or cost of capital, or ARP experiences any of the other impacts to its liquidity discussed below, the MGP’s ability to continue the Partnership’s operations and to fund the Partnership’s obligations for at least the next twelve months, as necessary, may be impacted.

~~ARP’s~~Liquidity ~~revolving credit facility is currently in the process of its semi-annual redetermination. Based on projected market conditions, continued declines in commodity prices~~ and ~~recent~~Capital ~~conversations~~Resources with its administrative agent, ARP expects that its borrowing base will be redetermined to a level below its outstanding borrowings as of March 31, 2016. If ARP’s borrowing base is redetermined below its current outstanding borrowings and ARP is unable to repay the deficiency or deposit additional collateral to eliminate such deficiency, or if ARP experiences any other event of default on its debt obligations, or if other debt agreements cross-default, and the lenders accelerate the maturity of any other outstanding debts, the MGP, may not have sufficient liquidity to continue the Partnership’s operations and to fund the Partnership’s obligations, and as a result, there would be substantial doubt regarding the Partnership’s ability to continue as a going concern.

~~If,~~We ~~however,~~are generally limited to the ~~MGP~~amount ~~were~~of tofunds ~~decide~~generated toby ~~liquidate~~the cash flow from our operations to fund our obligations and make distributions, if any, to our partners. Prices for oil and natural gas began to decline significantly during the ~~liquidation~~fourth ~~valuation~~quarter of ~~the~~2014 ~~Partnership’s~~and ~~assets~~have continued to decline and ~~liabilities~~remain ~~would~~low bein ~~determined~~2016. byThese anlower ~~independent~~commodity ~~expert~~prices have negatively impacted our revenues, earnings and cash flows. ItSustained islow ~~possible~~commodity ~~that~~prices ~~based~~will have a material and adverse effect on ~~such~~our ~~determination~~liquidity position. In addition, we ~~would~~have ~~not~~experienced besignificant ~~able~~downward revisions of its natural gas and oil reserves volumes and values due to ~~make~~the ~~any~~declines ~~liquidation~~in ~~distributions~~commodity prices. The MGP continues to implement various cost saving measures to reduce our ~~limited~~operating ~~partners.~~and Ageneral ~~liquidation~~and ~~could~~administrative ~~result~~costs, inincluding renegotiating contracts with contractors, suppliers and service providers, reducing the ~~transfer~~number of ~~the~~staff ~~post-liquidation~~and ~~assets~~contractors and ~~liabilities~~deferring ofand ~~the~~eliminating ~~Partnership~~discretionary costs. The MGP will continue to ~~the~~be ~~MGP~~strategic in managing our cost structure and, ~~would~~in ~~occur~~turn, ~~without~~liquidity ~~any~~to ~~further~~meet ~~contributions~~our ~~from~~operating needs. To the extent commodity prices remain low or ~~distributions~~decline further, or we experience other disruptions in the industry, our ability to fund our operations and make distributions may be further impacted, and could result in the ~~limited~~MGP’s ~~partners~~decision to liquidate our operations.

~~There~~If, ~~was~~however, nothe ~~cash~~MGP ~~provided~~were byto ~~operating~~decide ~~activities~~to ~~for~~liquidate ~~the~~our ~~three~~operations, ~~months~~the ~~ended~~liquidation ~~March~~valuation ~~31,~~of ~~2016~~our assets and ~~2015.~~liabilities ~~The~~would ~~change~~be indetermined ~~asset~~by ~~retirement~~an ~~receivable-affiliate~~independent ~~decreased~~expert. ~~$99,000,~~It ~~the~~is ~~change~~possible inthat ~~accounts~~based ~~receivable~~on ~~trade-affiliate~~such ~~decreased $75~~determination,~~700,~~ ~~and~~we ~~net~~would ~~earnings~~not ~~before~~be ~~depletion~~able ~~and~~to ~~accretion~~make ~~decreased~~any ~~$4,600~~liquidation distributions to our limited partners. ~~The~~A ~~change~~liquidation could result in ~~accounts~~the ~~payable~~transfer ~~trade~~of the post-~~affiliate~~liquidation ~~increased~~assets ~~$172,600,~~and liabilities of the ~~change~~Partnership into ~~non-cash~~the ~~gain~~MGP ~~(loss)~~and onwould ~~derivative~~occur ~~value~~without ~~increase~~any ~~$3,800~~further ~~and~~contributions ~~the~~from ~~change~~or indistributions ~~accrued~~to ~~liabilities~~the ~~increase~~limited ~~$2,900~~partners.

~~Our~~Historically, ~~MGP~~there ~~may~~has ~~withhold~~been no need to borrow funds ~~for~~from ~~future~~the ~~plugging~~MGP to fund operations as the cash flow from our operations have been adequate to fund our obligations and ~~abandonment~~distributions ~~costs.~~to ~~Through~~our ~~March~~partners. 31However, ~~2016,~~the recent significant declines in commodity prices have challenged our ~~MGP~~ability ~~withheld~~to ~~$420,700~~fund ofour ~~funds~~operations and may make it uneconomical for ~~this~~us ~~purpose.~~to ~~Any~~produce ~~additional~~our ~~funds,~~wells ifuntil ~~required~~they are depleted as we originally intended. Accordingly, ~~will~~the beMGP ~~obtained~~determined ~~from~~that ~~production~~there ~~revenues~~is orsubstantial ~~borrowings~~doubt ~~from~~about our ability to continue as a going concern. The MGP orintends, ~~its~~as ~~affiliates~~necessary, ~~which~~to ~~are~~continue ~~not~~our ~~contractually~~operations ~~committed~~and to ~~make~~fund ~~loans~~our toobligations usfor at least the next twelve months. ~~The~~To ~~amount~~the ~~that~~extent wecommodity ~~may~~prices ~~borrow~~remain atlow ~~any~~or ~~one~~decline ~~time~~further ~~may~~or ~~not~~ARP atis ~~any~~unsuccessful ~~time~~in ~~exceed~~completing 5%its ofRestructuring ~~our~~(as ~~total~~defined ~~subscriptions~~below) or the Plan (as defined below), ~~and~~the weMGP’s ~~will~~ability ~~not~~to ~~borrow~~continue ~~from~~our ~~third-parties.~~operations may be further impacted.

ARP Restructuring and Chapter 11 Bankruptcy Proceedings

There was no cash provided by operating activities for the six months ended June 30, 2016 and 2015. The change in asset retirement receivable-affiliate decreased $99,000, the change in accounts receivable trade-affiliate decreased $32,600, and net earnings before depletion and accretion decreased $35,700. The change in accounts payable trade-affiliate increased $152,300, the change in non-cash gain (loss) on derivative value increased $9,700 and the change in accrued liabilities increased $5,300.

Our MGP may withhold funds for future plugging and abandonment costs. Through June 30, 2016, our MGP withheld $519,700 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.

Critical Accounting Policies

~~For~~See aNote ~~more~~2 ~~complete~~to ~~discussion of the accounting policies and estimates that we have identified as critical in the preparation of~~ our condensed ~~consolidated~~ 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~~additional ~~fiscal~~information ~~year~~related ~~ended~~to ~~December~~recently ~~31,~~issued ~~2015~~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.

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 ~~March~~June 3130, 2016, 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

ITEM 6.

EXHIBITS

EXHIBIT INDEX

Exhibit No.		Description
4.0		Amended and Restated Certificate and Agreement of Limited Partnership for Atlas America Public #11-2002 LTD. (1)
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

(1) Filed on October 11, 2002 in the Form S-1/A Registration Statement dated October 11, 2002, File No. 333-90980

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 #11-2002 LTD.
		By: Atlas Resources, LLC, its Managing General Partner
Date: May 23, 2016		By: /s/ FREDDIE M. KOTEK
Date: August 15, 2016		By: /s/ FREDDIE M. KOTEK
		Freddie M. Kotek, Chief Executive Officer and President of the Managing General Partners

Date: ~~May~~August 2315, 2016 By: /s/ JEFFREY M. SLOTTERBACK Jeffrey M. Slotterback, Chief Financial Officer of the Managing General Partner

Filing Compare · ATLAS AMERICA PUBLIC #11-2002 LTD.