Atlas Resources Public #18-2009 10Q 2016 Q2 Quarterly report

United States

Securities and Exchange Commission

Washington, D.C. 20549

Form 10-Q

(Mark One)

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

For the quarterly period ended June 30, 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 333-150925-01

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

(Name of small business issuer in its charter)

Delaware		27-0213766
(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 RESOURCES PUBLIC #18-2009 (C) L.P.

(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 June 30, 2016 and December 31, 2015	3
	Condensed Statements of Operations for the Three and Six Months ended June 30, 2016 and 2015	4
	Condensed Statements of Comprehensive (Loss) Income for the Three and Six Months ended June 30, 2016 and 2015	5
	Condensed Statement of Changes in Partners’ Capital for the Six Months ended June 30, 2016	6
	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	17
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 RESOURCES PUBLIC #18-2009 (C) L.P.

CONDENSED BALANCE SHEETS

(Unaudited)

	June 30, 2016		December 31, 2015
	June 30, 2016		December 31, 2015
ASSETS
Current assets:
Cash	$	885,800	$	170,900
Accounts receivable trade–affiliate		896,700		1,332,000
Current portion of derivative assets		358,100		1,012,600
Total current assets		2,140,600		2,515,500
Gas and oil properties, net		33,994,500		35,360,600
Long-term asset retirement receivable-affiliate		176,900		136,900
Total assets	$	36,312,000	$	38,013,000

LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable trade-affiliate	$	363,100	$	-
Accrued liabilities		60,400		49,700
Put premiums payable-affiliate		96,300		197,700
Total current liabilities		519,800		247,400
Asset retirement obligations		3,299,700		3,225,100
Commitments and contingencies (Note 6)
Partners’ capital:
Managing general partner’s interest		2,269,000		2,384,400
Limited partners’ interest (22,928.90 units)		30,223,100		32,155,400
Accumulated other comprehensive income		400		700
Total partners’ capital		32,492,500		34,540,500
Total liabilities and partners’ capital	$	36,312,000	$	38,013,000

See accompanying notes to condensed financial statements.

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016		2015
REVENUES
Natural gas	$	1,210,800	$	1,504,900		$	2,409,100	$	4,216,200
(Loss) gain on mark-to-market derivatives		(167,800)		127,500			6,800		224,600
Total revenues		1,043,000		1,632,400			2,415,900		4,440,800
COSTS AND EXPENSES
Production		653,100		959,900			1,500,200		2,078,300
Depletion		641,100		710,400			1,366,100		1,412,900
Accretion of asset retirement obligations		37,300		43,600			74,600		87,200
General and administrative		39,700		37,200			79,300		75,600
Total costs and expenses		1,371,200		1,751,100			3,020,200		3,654,000
Net (loss) income	$	(328,200)	$	(118,700	)	$	(604,300)	$	786,800
Allocation of net (loss) income:
Managing general partner	$	88,300	$	130,500		$	110,700	$	425,300
Limited partners	$	(416,500)	$	(249,200	)	$	(715,000)	$	361,500
Net (loss) income per limited partnership unit	$	(18)	$	(11	)	$	(31)	$	16

See accompanying notes to condensed financial statements.

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

CONDENSED STATEMENTS OF COMPREHENSIVE (LOSS) INCOME

(Unaudited)

	Three Months Ended					Six Months Ended
	June 30,					June 30,
	2016		2015			2016		2015
Net (loss) income	$	(328,200)	$	(118,700	)	$	(604,300)	$	786,800
Other comprehensive loss:
Difference in estimated hedge receivable		-		(231,400	)		-		(99,000	)
Reclassification adjustment to net (loss) income of mark-to-market gains on cash flow hedges		(100)		230,800			(300)		97,900
Total other comprehensive loss		(100)		(600	)		(300)		(1,100	)
Comprehensive (loss) income	$	(328,300)	$	(119,300	)	$	(604,600)	$	785,700

See accompanying notes to condensed financial statements.

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

FOR THE SIX MONTHS ENDED

June 30, 2016

(Unaudited)

	Managing General Partner		Limited Partners		Accumulated Other Comprehensive Income (Loss)		Total
Balance at December 31, 2015	$	2,384,400	$	32,155,400	$	700	$	34,540,500
Participation in revenues, costs and expenses:
Net production revenues		273,100		635,800		-		908,900
Gain on mark-to-market derivatives		-		6,800		-		6,800
Depletion		(119,400)		(1,246,700)		-		(1,366,100)
Accretion of asset retirement obligations		(20,800)		(53,800)		-		(74,600)
General and administrative		(22,200)		(57,100)		-		(79,300)
Net income (loss)		110,700		(715,000)		-		(604,300)
Other comprehensive loss		-		-		(300)		(300)
Distributions to partners		(226,100)		(1,217,300)		-		(1,443,400)
Balance at June 30, 2016	$	2,269,000	$	30,223,100	$	400	$	32,492,500

See accompanying notes to condensed financial statements.

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six Months Ended June 30,
	Six Months Ended June 30,
	2016		2015
Cash flows from operating activities:
Net (loss) income	$	(604,300)	$	786,800
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depletion		1,366,100		1,412,900
Non-cash loss on derivative value		552,800		308,700
Accretion of asset retirement obligations		74,600		87,200
Changes in operating assets and liabilities:
Decrease in accounts receivable trade-affiliate		435,300		1,256,400
Increase in asset retirement receivable-affiliate		(40,000)		(73,700	)
Increase in accounts payable trade-affiliate		363,100		-
Increase (decrease) in accrued liabilities		10,700		(19,800	)
Net cash provided by operating activities		2,158,300		3,758,500
Cash flows from investing activities:
Proceeds from sale of tangible equipment		-		1,300
Net cash provided by investing activities		-		1,300
Cash flows from financing activities:
Distributions to partners		(1,443,400)		(3,759,800	)
Net cash used in financing activities		(1,443,400)		(3,759,800	)
Net change in cash		714,900		-
Cash at beginning of period		170,900		-
Cash at end of period	$	885,800	$	-

See accompanying notes to condensed financial statements.

ATLAS RESOURCES PUBLIC #18-2009 (C) L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

June 30, 2016

(Unaudited)

NOTE 1 - DESCRIPTION OF BUSINESS

Atlas Resources Public #18-2009 (C) L.P. is a Delaware limited partnership, formed on June 9, 2009 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”) (OTC: ARPJ). Unless the context otherwise requires, references to “the Partnership,” “we,” “us” and “our”, refer to Atlas Resources Public #18-2009 (C) L.P.

Atlas Energy Group, LLC (“Atlas Energy Group”; 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, Tennessee and Indiana. 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. Produced natural gas 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.

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 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.

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.

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. To the extent commodity prices remain low or decline further or ARP is unsuccessful in completing its Restructuring (as defined below) or the Plan (as defined below), the MGP’s ability to continue the Partnership’s operations may 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. In June 2016, the MGP transferred $676,700 of funds to the Partnership based on projected monthly distributions to their limited partners over the next several months to ensure accessible distribution funding coverage in accordance with the Partnership’s operations and partnership agreements in the event the MGP experiences a prolonged restructuring period as the MGP performs all administrative and management functions for the Partnerships. 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 differ from those estimates.

Gas and Oil Properties

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

	June 30, 2016		December 31, 2015
	June 30, 2016		December 31, 2015
Proved properties:
Leasehold interests	$	2,739,900	$	2,739,900
Wells and related equipment		242,161,100		242,161,100
Total natural gas and oil properties		244,901,000		244,901,000
Accumulated depletion and impairment		(210,906,500)		(209,540,400	)
Gas and oil properties, net	$	33,994,500	$	35,360,600

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 sheets at June 30, 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 New York Mercantile Stock Exchange (“NYMEX”) futures and options contracts and non-regulated over-the-counter futures contracts with qualified counterparties. NYMEX contracts are generally settled with offsetting positions, but may be settled by the physical delivery of the commodity. These contracts have been recorded at their fair values.

The Partnership reflected net derivative assets on its condensed balance sheets of $358,100 and $1,012,600 at June 30, 2016 and December 31, 2015, respectively.

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

	Three Months Ended June 30,									Six Months Ended June 30,
	2016				2015					2016		2015
Gain (loss) reclassified from accumulated other comprehensive income into natural gas and liquids revenues	$		100		$		(230,800		)	$	300	$	(97,900	)
(Losses) gains subsequent to hedge accounting recognized in (loss) gain on mark-to-market derivatives		$		(167,800)		$		127,500		$	6,800	$	224,600

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

Natural Gas Fixed Price Swaps - Limited Partners

Production Period Ending December 31,	Volumes ⁽³⁾		Average Fixed Price		Fair Value Asset⁽²⁾
	(MMBtu)⁽¹⁾		(per MMBtu)⁽¹⁾
2016		150,100	$	4.46	$	216,300

Natural Gas Put Options - Limited Partners

Production Period Ending December 31,	Volumes		Average Fixed Price		Fair Value Asset⁽²⁾
	(MMBtu)⁽¹⁾		(per MMBtu)⁽¹⁾
2016		125,400	$	4.15	$	141,800
Limited Partner’s Commodity Derivatives, net					$	358,100

(1)

“MMBtu” represents million British Thermal Units.

(2)

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

(3)

The production volume for 2016 include the remaining six months of 2016 beginning July 1, 2016.

At June 30, 2016, the MGP had a secured hedge facility agreement with a syndicate of banks under which the Partnership has the ability to enter into derivative contracts to manage its exposure to commodity price movements. Under the MGP’s revolving credit facility, the Partnership is required to utilize this secured hedge facility for future commodity risk management activity. The Partnership’s obligations under the facility are secured by mortgages on its gas and oil properties and first priority security interests in substantially all of its assets and are guaranteed by the MGP. The MGP administers the commodity price risk management activity for the Partnership under the secured hedge facility. The secured hedge facility agreement contains covenants that limit the Partnership’s ability to incur indebtedness, grant liens, make loans or investments, make distributions if a default under the secured hedge facility agreement exists or would result from the distribution, merge into or consolidate with other persons, enter into commodity or interest rate swap agreements that do not conform to specified terms or that exceed specified amounts, or engage in certain asset dispositions, including a sale of all or substantially all of its assets. As of June 30, 2016 only the Partnership’s natural gas swaps are included in the secured hedge facility.

An event of default occurred under the secured hedging facility agreement upon the MGP’s filing of voluntary petitions for relief under Chapter 11. The lenders under the secured hedge facility agreed to forbear from exercising remedies in respect of such event of default while the Chapter 11 filings are pending and, upon occurrence of the effective date of the Plan contemplated by the Restructuring Support Agreement, such event of default will no longer be deemed to exist or to continue under the secured hedge facility.

In addition, it will be an event of default under the MGP’s revolving credit facility if the MGP breaches an obligation governed by the secured hedge facility, and the effect of such breach is to cause amounts owing under swap agreements governed by the secured hedge facility to become immediately due and payable.

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 June 30, 2016 and December 31, 2015, all derivative financial instruments were classified as Level 2.

Information for assets measured at fair value at June 30, 2016 and December 31, 2015 is as follows:

	Level 1		Level 2		Level 3		Total
As of June 30, 2016
Derivative assets, gross
Commodity swaps	$	-	$	216,300	$	-	$	216,300
Commodity puts		-		141,800		-		141,800
Total derivative assets, gross	$	-	$	358,100	$	-	$	358,100

	Level 1		Level 2		Level 3		Total
As of December 31, 2015
Derivative assets, gross
Commodity swaps	$	-	$	584,600	$	-	$	584,600
Commodity puts		-		428,000		-		428,000
Total derivative assets, gross	$	-	$	1,012,600	$	-	$	1,012,600

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 expenses in the Partnership’s condensed statements of operations, are payable at $975 per well per month for Marcellus wells, $1,500 per well per month for New Albany wells, and for all other wells a fee of $392 is charged 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 16% 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 June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
Administrative fees	$	16,600	$	17,800	$	32,500	$	35,800
Supervision fees		230,100		253,100		451,900		512,000
Transportation fees		184,400		241,900		360,500		572,100
Direct costs		261,700		484,300		734,600		1,034,000
Total	$	692,800	$	997,100	$	1,579,500	$	2,153,900

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

Subordination by Managing General Partner

Under the terms of the Partnership Agreement, the MGP may be required up to 50% of its share of net production revenues so that the limited partners receive a return of at least 10% of their net subscriptions, determined on a cumulative basis, in each of the first five years of Partnership operations, commencing with the first distribution to the limited partners (August 2010). The subordination period expired in August 2015.

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 June 30, 2016, the MGP withheld $176,900 of net production revenue for future plugging and abandonment costs.

Legal Proceedings

The Partnership and affiliates of the MGP and their subsidiaries are party to various routine legal proceedings arising out of the ordinary course of its business. Management and the 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 Resources Public #18-2009 (C) L.P. is a Delaware limited partnership, formed on June 9, 2009 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”) (OTCQX: ARPJ). Unless the context otherwise requires, references to “the Partnership”, “we” “us” and “our”, refer to Atlas Resources Public #18-2009 (C) L.P.

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, Tennessee, and Indiana. 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;

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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 June 30, 2016, our MGP withheld $176,900 of net production revenues for this purpose.

Markets and Competition

The availability of a ready market for natural gas 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 producing countries and regions, market demand, competition from other energy sources, the effect of federal regulation on the sale of natural gas in interstate commerce, other governmental regulation of the production and transportation of natural gas 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. Product availability and price are the principal means of competing in selling natural gas 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 Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
Production revenues (in thousands):
Gas	$	1,211		$	1,505		$	2,409		$	4,216

Production volumes:
Gas (mcf/day)⁽¹⁾		9,336			12,410			9,908			12,414

Average sales prices: ⁽²⁾
Gas (per mcf) ^{(1) (3)}	$	1.53		$	1.58		$	1.43		$	2.11

Production costs:
As a percent of revenues		54	%		64	%		62	%		49	%
Per mcfe⁽¹⁾	$	0.77		$	0.85		$	0.83		$	0.92

Depletion per mcfe	$	0.75		$	0.63		$	0.76		$	0.63

(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 after adjusting for the effect of previously recognized gains resulting from prior period impairment charges.

(3)

Average gas prices are calculated by including in total revenue derivative gains previously recognized into income in connection with prior period impairment charges and dividing by total volume for the period. Previously recognized gains were $90,700 and $275,000 for the three months ended June 30, 2016 and 2015, respectively. Previously recognized gains were $168,000 and $533,300 for the six months ended June 30, 2016 and 2015, respectively.

Natural Gas Revenues. Our natural gas revenues were $1,210,800 and $1,504,900 for the three months ended June 30, 2016 and 2015, respectively, a decrease of $294,100 (20%). The $294,100 decrease in natural gas revenues for the three months ended June 30, 2016 as compared to the prior year similar period was attributable to a $372,800 decrease in production volumes partially offset by a $78,700 increase in our natural gas sales prices after the effect of financial hedges, which were driven by market conditions. Our production volumes decreased to 9,336 mcf per day for the three months ended June 30, 2016 from 12,410 mcf per day for the three months ended June 30, 2015, a decrease of 3,074 mcf per day (25%). The overall decrease in natural gas production volumes for the three months ended June 30, 2016 as compared to the prior year similar period resulted primarily from the normal decline inherent in the life of a well in addition to well shut-in due to it being uneconomical to continue production in the current pricing environment.

Our natural gas revenues were $2,409,100 and $4,216,200 for the six months ended June 30, 2016 and 2015, respectively, a decrease of $1,807,100 (43%). The $1,807,100 decrease in natural gas revenues for the six months ended June 30, 2016 as compared to the prior year similar period was attributable to a $974,700 decrease in our natural gas sales prices after the effect of financial hedges, which were driven by market conditions, and a $832,400 decrease in production volumes. Our production volumes decreased to 9,908 mcf per day for the six months ended June 30, 2016 from 12,414 mcf per day for the six months ended June 30, 2015, a decrease of 2,506 mcf per day (20%). The overall decrease in natural gas production volumes for the six months ended June 30, 2016 as compared to the prior year similar period resulted primarily from the normal decline inherent in the life of a well in addition to well shut-in due to it being uneconomical to continue production in the current pricing environment.

(Loss) Gain on Mark-to-Market Derivatives. We recognize changes in the fair value of our derivatives immediately within (loss) gain on mark-to-market derivatives on our condensed statements of operations.

We recognized a loss on mark-to-market derivatives of $167,800 and a $127,500 gain on mark-to-market derivatives for the three months ended June 30, 2016 and 2015, respectively. We recognized a gain on mark-to-market derivatives of $6,800 and $224,600 for the six months ended June 30, 2016 and 2015, respectively. These (losses) gains were due to mark-to-market (losses) gains primarily related to the change in natural gas prices during the periods.

Costs and Expenses. Production expenses were $653,100 and $959,900 for the three months ended June 30, 2016 and 2015, respectively, a decrease of $306,800 (32%). Production expenses were $1,500,200 and $2,078,300 for the six months ended June 30, 2016 and 2015, respectively, a decrease of $578,100 (28%). These decreases were mostly attributable to decreases in transportation costs and other direct costs.

Depletion of gas and oil properties as a percentage of gas and oil revenues was 53% and 47% for the three months ended June 30, 2016 and 2015, respectively, and 57% and 34% for the six months ended June 30, 2016 and 2015, respectively. This change was primarily attributable to changes in revenues, gas reserve quantities, and to a lesser extent, revenues, product prices and production volumes and changes in the depletable cost basis of gas and oil properties.

General and administrative expenses for the three months ended June 30, 2016 and 2015 were $39,700 and $37,200, respectively, an increase of $2,500 (7%). For the six months ended June 30, 2016 and 2015, these expenses were $79,300 and $75,600, respectively, an increase of $3,700 (5%). These expenses include third-party costs for services as well as the monthly administrative fees charged by our MGP and vary from period to period due to the costs charged to us and services provided to us.

Liquidity and Capital Resources

We are generally limited to the amount of funds generated by 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 fourth quarter of 2014 and have continued to decline and remain low in 2016. These lower commodity prices have negatively impacted our revenues, earnings and cash flows. Sustained low commodity prices will have a material and adverse effect on our liquidity position. In addition, we have 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 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. The MGP will continue to be strategic 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.

If, however, the MGP were to decide to liquidate our operations, the liquidation valuation of our 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.

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 for us 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. To the extent commodity prices remain low or decline further or ARP is unsuccessful in completing its Restructuring (as defined below) or the Plan (as defined below), the MGP’s ability to continue our operations may be further impacted.

ARP Restructuring and Chapter 11 Bankruptcy Proceedings

Cash provided by operating activities decreased $1,600,200 for the six months ended June 30, 2016 to $2,158,300 as compared to $3,758,500 for the six months ended June 30, 2015. This decrease was due to a decrease in net earnings before depletion and accretion of $1,450,500 and a decrease in the change in accounts receivable trade-affiliate of $821,100. This decrease was partially offset by an increase in the change in accrued liabilities of $30,500, an increase in the non-cash (loss) gain on derivative value of $244,100, an increase in the change in accounts payable trade-affiliate of $363,100, and an increase in the change in asset retirement receivable-affiliate of $33,700 for the six months ended June 30, 2016 as compared to the six months ended June 30, 2015.

There was no cash provided by investing activities for the six months ended June 30, 2016. Cash proved by investing activities was $1,300 for the six months ended June 30, 2015 resulting from proceeds from the sale of tangible equipment.

Cash used in financing activities decreased $2,316,400 during the six months ended June 30, 2016 to $1,443,400 from $3,759,800 for the six months ended June 30, 2015. This decrease was due to a decrease in cash distributions to partners.

Our MGP may withhold funds for future plugging and abandonment costs. Through June 30, 2016, our MGP withheld $176,900 of funds for this purpose. Any additional funds, if required, will be obtained from production revenues or borrowings from our MGP or its affiliates, which are not contractually committed to make loans to us. The amount that we may borrow at any one time may not at any time exceed 5% of our total subscriptions, and we will not borrow from third-parties.

Critical Accounting Policies

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

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

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 June 30, 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

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.

ITEM 6.

EXHIBITS

EXHIBIT INDEX

Exhibit No.		Description

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

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

32.1		Section 1350 Certification

32.2		Section 1350 Certification

101		Interactive Data File

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 Resources Public #18-2009 (C) L.P.

	By:	Atlas Resources, LLC, its
		Managing General Partner

Date: August 15, 2016	By:	/s/ FREDDIE M. KOTEK
		Freddie M. Kotek, Chief Executive Officer and President of the Managing General Partner

Date: August 15, 2016

By:

/s/ JEFFREY M. SLOTTERBACK

Jeffrey M. Slotterback

Chief Financial Officer of the

Managing General Partner

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Atlas Resources Public #18-2009 Inactive 10-Q2016 Q2 Quarterly report

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