UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

 

FORM 10-Q

 

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

For the quarterly period ended June 30, 2014

 

OR

 

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

For the transition period from ___________to ____________

  

Commission File No. 000-53959

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P. 

 

Delaware		26-4280211
(State or jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)
3901 South Broadway, Tyler, Texas		75701
(Address of principal executive offices)		(Zip code)
Registrant’s Telephone Number, including area code:	(903) 561-2900

 

Not Applicable

(Former name, former address and former fiscal year, if changed since last report)

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 of 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes☒ No ☐

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    

Yes☒ No ☐

 

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

 

	Large accelerated filer  ☐		Accelerated filer  ☐
	Non-accelerated filer    ☐	(Do not check if a smaller reporting company)	Smaller reporting company ☒

 

Indicate by check mark if the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes☐ No ☒

  

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

INDEX
Part 1  -  Financial Information				Page No.
	Item 1.  Financial Statements
		Condensed Balance Sheets -
			June 30, 2014  (Unaudited) and December 31, 2013	3
		Condensed Statements of Operations (Unaudited) -
			For the three months ended June 30, 2014 and 2013
			and the six months ended June 30, 2014 and 2013	4
		Condensed Statement of Changes In Partners' Capital (Unaudited) -
			For the six months ended June 30, 2014	5
		Condensed Statements of Cash Flows (Unaudited) -
			For the six months ended June 30, 2014 and 2013	6
		Notes to Condensed Financial Statements		7
	Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations			9
	Item 3.  Quantitative and Qualitative Disclosures about Market Risk			12
	Item 4.  Disclosure Controls and Procedures			12
Part II  -  Other Information
	Item 1.  Legal Proceedings			13
	Item 6.  Exhibits and Reports on Form 8-K			13

 

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

Part I - Financial Information

 

Item 1.  Financial Statements

 

CONDENSED BALANCE SHEETS

  

		June 30, 2014				December 31, 2013
		(Unaudited)
ASSETS
Cash		$	9,587			$	1,873
Accounts receivable, affiliate			1,469,227				1,478,835
Prepaid state taxes			18,028				7,500
Total current assets			1,496,842				1,488,208
Oil and gas properties at cost, full-cost method			63,722,500				63,736,487
Less accumulated depreciation, depletion,
amortization and impairment			(34,563,437	)			(33,396,019	)
			29,159,063				30,340,468
Total assets		$	30,655,905			$	31,828,676
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable, affiliate		$	239,643			$	257,383
Total current liabilities			239,643				257,383
Asset retirement obligation			1,071,392				1,064,146
Partners' capital			29,344,870				30,507,147
Total liabilities and partners' capital		$	30,655,905			$	31,828,676

 

The accompanying notes are an integral part of the financial statements.

 

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

CONDENSED STATEMENTS OF OPERATIONS

(Unaudited)

 

		For the								For the
		Three Months Ended								Six Months Ended
		June 30,								June 30,
		2014				2013				2014				2013
Revenues and other income:
Oil sales		$	1,431,221			$	2,056,140			$	2,630,511			$	3,388,812
Gas sales			903,263				910,524				1,918,379				1,773,282
Interest income			143				—				143				—
Total revenues and other income			2,334,627				2,966,664				4,549,033				5,162,094
Expenses:
Lease operating expense			343,976				351,193				719,034				749,745
Production taxes			120,522				127,904				228,568				214,872
Administrative and general expense			110,787				102,888				196,299				207,286
Depreciation, depletion, and amortization			610,743				817,491				1,166,829				1,476,815
Cost ceiling write-down			—				1,286,337				—				1,286,337
Asset retirement obligation accretion			10,857				10,397				21,716				20,774
Total expenses			1,196,885				2,696,210				2,332,446				3,955,829
Net income		$	1,137,742			$	270,454			$	2,216,587			$	1,206,265
Basic and diluted net income per
partner interest
(13,242 interests outstanding)		$	85.92			$	20.42			$	167.39			$	91.09

 

The accompanying notes are an integral part of the financial statements.

 

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL

For the six months ended June 30, 2014

 (Unaudited)

 

		Total
Balance at December 31, 2013		$	30,507,147
Cash distributions			(3,378,864	)
Net income			2,216,587
Balance at June 30, 2014		$	29,344,870

 

The accompanying notes are an integral part of the financial statements.

 

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

  

		Six Months Ended
		June 30,
		2014				2013
Cash flows from operating activities:
Net income		$	2,216,587			$	1,206,265
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization			1,166,829				1,476,815
Cost ceiling write-down			—				1,286,337
Asset retirement obligation accretion			21,716				20,774
Plugging and abandonment cost paid from asset retirement obligation			—				(1,449	)
Changes in operating assets and liabilities:
Accounts receivable, affiliate			9,608				(384,237	)
Prepaid state taxes			(10,528	)			(5,000	)
Accounts payable, affiliate			(17,740	)			126,413
Net cash provided by operating activities			3,386,472				3,725,918
Cash flows from investing activities:
Proceeds from sale of oil and gas properties			106				—
Purchase and development of oil and gas properties			—				(76,097	)
Net cash provided by (used in) investing activities			106				(76,097	)
Cash flows from financing activities:
Cash distributions to partners			(3,378,864	)			(3,695,916	)
Net cash used in financing activities			(3,378,864	)			(3,695,916	)
Net increase (decrease) in cash			7,714				(46,095	)
Cash, beginning of period			1,873				46,485
Cash, end of period		$	9,587			$	390
Supplemental Cash Flow Information:
Non-cash changes to net oil & gas properties related to
asset retirement obligation liabilities		$	(14,470	)		$	(11,123	)

 

The accompanying notes are an integral part of the financial statements.

 

 

MEWBOURNE ENERGY PARTNERS 09-A, L.P.

 

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

 

1.    Description of Business

 

Mewbourne Energy Partners 09-A, L.P., (the “Registrant” or the “Partnership”), a Delaware limited partnership engaged primarily in oil and gas development and production in Texas, Oklahoma, and New Mexico, was organized on February 26, 2009. The offering of limited and general partner interests began May 1, 2009 as a part of a private placement pursuant to Section 4(2) of the Securities Act of 1933 and Regulation D promulgated thereunder, and concluded August 28, 2009, with total investor contributions of $66,210,000 originally being sold to accredited investors of which $62,140,000 were sold to accredited investors as general partner interests and $4,070,000 were sold to accredited investors as limited partner interests. During 2011, all general partner equity interests were converted to limited partner equity interests. In accordance with the laws of the State of Delaware, Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Partnership’s managing general partner. MD has no significant equity interest in the Partnership.

 

2.    Summary of Significant Accounting Policies

 

Reference is hereby made to the Registrant’s Annual Report on Form 10-K for 2013, which contains a summary of significant accounting policies followed by the Partnership in the preparation of its financial statements. These policies are also followed in preparing the quarterly report included herein.

 

In the opinion of management, the accompanying unaudited financial statements contain all adjustments of a normal recurring nature necessary to present fairly our financial position, results of operations, cash flows and partners’ capital for the periods presented. The results of operations for the interim periods are not necessarily indicative of the final results expected for the full year.

 

3.    Accounting for Oil and Gas Producing Activities

 

The Partnership follows the full-cost method of accounting for its oil and gas activities. Under the full-cost method, all productive and non-productive costs incurred in the acquisition, exploration and development of oil and gas properties are capitalized. Depreciation, depletion and amortization of oil and gas properties subject to amortization is computed on the units-of-production method based on the proved reserves underlying the oil and gas properties. At June 30, 2014 and 2013, all capitalized costs were subject to amortization. Proceeds from the sale or other disposition of properties are credited to the full cost pool. Gains and losses on the sale or other disposition of properties are not recognized unless such adjustments would significantly alter the relationship between capitalized costs and the proved oil and gas reserves. Capitalized costs are subject to a quarterly ceiling test that limits such costs to the aggregate of the present value of future net cash flows of proved reserves and the lower of cost or fair value of unproved properties. There was a cost ceiling write-down of $1,286,337 on June 30, 2013 due to lower average oil and gas prices for the twelve months preceding the write-down. There were no cost ceiling write-downs on March 31, 2013, March 31, 2014, or June 30, 2014.

 

 

4.    Asset Retirement Obligations

 

The Partnership has recognized an estimated liability for future plugging and abandonment costs. A liability for the estimated fair value of the future plugging and abandonment costs is recorded with a corresponding increase in the full cost pool at the time a new well is drilled. Depreciation expense associated with estimated plugging and abandonment costs is recognized in accordance with the full cost methodology.

 

The Partnership estimates a liability for plugging and abandonment costs based on historical experience and estimated well life. The liability is discounted using the credit-adjusted risk-free rate. Revisions to the liability could occur due to changes in well plugging and abandonment costs or well useful lives, or if federal or state regulators enact new well restoration requirements. The Partnership recognizes accretion expense in connection with the discounted liability over the remaining life of the well.

 

A reconciliation of the Partnership’s liability for well plugging and abandonment costs for the six months ended June 30, 2014 and the year ended December 31, 2013 is as follows:

 

		June 30,				December 31,
		2014				2013
Balance, beginning of period		$	1,064,146			$	1,033,851
Liabilities incurred			13				7,790
Liabilities reduced due to sale and plugging and abandonments			(14,483	)			(18,994	)
Accretion expense			21,716				41,499
Balance, end of period		$	1,071,392			$	1,064,146

 

5.    Related Party Transactions

 

In accordance with the laws of the State of Delaware, Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Partnership’s managing general partner. MD has no significant equity interest in the Partnership. Mewbourne Oil Company (“MOC”) is operator of oil and gas properties owned by the Partnership. Mewbourne Holdings, Inc. is the parent of both MD and MOC. Substantially all transactions are with MD and MOC.

 

In the ordinary course of business, MOC will incur certain costs that will be passed on to owners of the well for which the costs were incurred. The Partnership will receive their portion of these costs based upon their ownership in each well incurring the costs. These costs are referred to as operator charges and are standard and customary in the oil and gas industry. Operator charges include recovery of gas marketing costs, fixed rate overhead, supervision, pumping, and equipment furnished by the operator, some of which will be included in the full cost pool pursuant to Rule 4-10(c)(2) of Regulation S-X. Services and operator charges are billed in accordance with the program and partnership agreements.

 

In accordance with the Partnership agreement, during any particular calendar year the total amount of administrative expenses allocated to the Partnership by MOC shall not exceed the greater of (a) 3.5% of the Partnership’s gross revenue from the sale of oil and natural gas production during each year (calculated without any deduction for operating costs or other costs and expenses) or (b) the sum of $50,000 plus .25% of the capital contributions of limited and general partners.

 

 

The Partnership participates in oil and gas activities through the Program. The Partnership and MD are the parties to the Program, and the costs and revenues are allocated between them as follows:

 

			Partnership				MD
Revenues:
Proceeds from disposition of depreciable and depletable properties			75	%			25	%
All other revenues			75	%			25	%
Costs and expenses:
Organization and offering costs (1)			0	%			100	%
Lease acquisition costs (1)			0	%			100	%
Tangible and intangible drilling costs (1)			100	%			0	%
Operating costs, reporting and legal expenses, general and
administrative expenses and all other costs			75	%			25	%

 

(1)

Pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 15% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 15% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 15%. The Partnership’s financial statements reflect its respective proportionate interest in the Program.

 

 

Item 2.    Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

Liquidity and Capital Resources

 

Mewbourne Energy Partners 09-A, L.P. (“the Partnership”) was formed February 26, 2009. The offering of limited and general partnership interests began May 1, 2009 and concluded August 28, 2009, with total investor contributions of $66,210,000. During 2011, all general partner equity interests were converted to limited partner equity interests.

 

Future capital requirements and operations will be conducted with available funds generated from oil and gas activities. No bank borrowing is anticipated. The Partnership had net working capital of $1,257,199 at June 30, 2014.

 

During the six months ended June 30, 2014, the Partnership made cash distributions to the investor partners in the amount of $3,378,864 as compared to $3,695,916 for the six months ended June 30, 2013. The Partnership expects that cash distributions will continue during 2014 as additional oil and gas revenues are sufficient to produce cash flows from operations. Since inception, the Partnership has made distributions of $61,195,239, inclusive of state tax payments.

 

The sale of crude oil and natural gas produced by the Partnership will be affected by a number of factors that are beyond the Partnership’s control. These factors include the price of crude oil and natural gas, the fluctuating supply of and demand for these products, competitive fuels, refining, transportation, extensive federal and state regulations governing the production and sale of crude oil and natural gas, and other competitive conditions. It is impossible to predict with any certainty the future effect of these factors on the Partnership.

 

 

Results of Operations

 

For the three months ended June 30, 2014 as compared to the three months ended June 30, 2013:

 

		Three Months Ended June 30,
		2014				2013
Oil sales		$	1,431,221			$	2,056,140
Barrels produced			14,908				22,878
Average price/bbl		$	96.00			$	89.87
Gas sales		$	903,263			$	910,524
Mcf produced			153,911				178,721
Average price/mcf		$	5.87			$	5.09

 

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $632,180, a 21.3% decline, for the three months ended June 30, 2014 as compared to the three months ended June 30, 2013.

 

Of this decrease, $765,148 and $145,603 were due to declines in the volumes of oil and gas sold, respectively. The volumes fell by 7,970 barrels (bbls) and 24,810 thousand cubic feet (mcf) for the three months ended June 30, 2014 as compared to the three months ended June 30, 2013.

 

These decreases were partially offset by increases of $140,229 and $138,342 due to inclines in the average prices of oil and gas sold, respectively. The average price increased to $96.00 from $89.87 per bbl and to $5.87 from $5.09 per mcf for the three months ended June 30, 2014 as compared to the three months ended June 30, 2013.

 

Lease operations. Lease operating expense during the three month period ended June 30, 2014 fell to $343,976 from $351,193 for the three month period ended June 30, 2013 due to fewer well repairs and workovers.

 

Production taxes. Production taxes during the three month period ended June 30, 2014 decreased to $120,522 from $127,904 for the three month period ended June 30, 2013. This was due to lower overall oil and gas revenue for the three month period ended June 30, 2014.

 

Administrative and general expense. Administrative and general expense for the three month period ended June 30, 2014 increased to $110,787 from $102,888 for the three month period ended June 30, 2013 due to increased administrative expenses allocable to the Partnership and higher general expense for reporting and legal costs.

 

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended June 30, 2014 decreased to $610,743 from $817,491 for the three month period ended June 30, 2013. This was due to the net decrease in oil and gas production.

 

Cost ceiling write-down. There was a cost ceiling write-down of $1,286,337 on June 30, 2013 due to lower average oil and gas prices for the twelve months preceding the write-down. There was no cost ceiling write-down on June 30, 2014.

 

 

Results of Operations

 

For the six months ended June 30, 2014 as compared to the six months ended June 30, 2013:

 

		Six Months Ended June 30,
		2014				2013
Oil sales		$	2,630,511			$	3,388,812
Barrels produced			27,770				38,715
Average price/bbl		$	94.72			$	87.53
Gas sales		$	1,918,379			$	1,773,282
Mcf produced			299,067				350,472
Average price/mcf		$	6.41			$	5.06

 

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $613,204, an 11.9% decline, for the six months ended June 30, 2014 as compared to the six months ended June 30, 2013.

 

Of this decrease, $1,036,764 and $329,740 were due to declines in the volumes of oil and gas sold, respectively. The volumes fell by 10,945 barrels (bbls) and 51,405 thousand cubic feet (mcf) for the six months ended June 30, 2014 as compared to the six months ended June 30, 2013.

 

These decreases were partially offset by increases of $278,463 and $474,837 due to inclines in the average prices of oil and gas sold, respectively. The average price increased to $94.72 from $87.53 per bbl and to $6.41 from $5.06 per mcf for the six months ended June 30, 2014 as compared to the six months ended June 30, 2013.

 

Lease operations. Lease operating expense during the six month period ended June 30, 2014 fell to $719,034 from $749,745 for the six month period ended June 30, 2013 due to fewer well repairs and workovers.

 

Production taxes. Production taxes during the six month period ended June 30, 2014 increased to $228,568 from $214,872 for the six month period ended June 30, 2013. This was due to production tax credits received during the six month period ended June 30, 2013.

 

Administrative and general expense. Administrative and general expense decreased to $196,299 for the six month period ended June 30, 2014 from $207,286 for the six month period ended June 30, 2013 due to decreased administrative expenses allocable to the Partnership and lower general expense for reporting and legal costs.

 

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six month period ended June 30, 2014 decreased to $1,166,829 from $1,476,815 for the six month period ended June 30, 2013. This was due to the net decrease in oil and gas production.

 

Cost ceiling write-down. There was a cost ceiling write-down of $1,286,337 on June 30, 2013 due to lower average oil and gas prices for the twelve months preceding the write-down. There were no cost ceiling write-downs on March 31, 2013, March 31, 2014, or June 30, 2014.

 

 

Item 3.    Quantitative and Qualitative Disclosures about Market Risk

 

1.    Interest Rate Risk

 

The Partnership Agreement allows borrowings from banks or other financial sources of up to 20% of the total capital contributions to the Partnership without investor approval. Should the Partnership elect to borrow monies for additional development activity on Partnership properties, it will be subject to the interest rate risk inherent in borrowing activities. Changes in interest rates could significantly affect the Partnership’s results of operations and the amount of net cash flow available for partner distributions. Also, to the extent that changes in interest rates affect general economic conditions, the Partnership will be affected by such changes.

 

2.    Commodity Price Risk

 

The Partnership does not expect to engage in commodity futures trading or hedging activities or enter into derivative financial instrument transactions for trading or other speculative purposes.  The Partnership currently expects to sell a significant amount of its production from successful oil and gas wells on a month-to-month basis at market prices. Accordingly, the Partnership is at risk for the volatility in commodity prices inherent in the oil and gas industry, and the level of commodity prices will have a significant impact on the Partnership’s results of operations. For the six months ended June 30, 2014, a 10% change in the price received for oil and gas production would have had an approximate $455,000 impact on revenue.

 

 3.    Exchange Rate Risk

 

The Partnership currently has no income from foreign sources or operations in foreign countries that would subject it to currency exchange rate risk. The Partnership does not currently expect to purchase any prospects located outside of either the United States or United States coastal waters in the Gulf of Mexico.

 

 

Item 4.    Disclosure Controls and Procedures

 

MD maintains a system of controls and procedures designed to provide reasonable assurance as to the reliability of the financial statements and other disclosures included in this report, as well as to safeguard assets from unauthorized use or disposition. MD’s Chief Executive Officer and Chief Financial Officer have evaluated the effectiveness of the design and operation of its disclosure controls and procedures with the assistance and participation of other members of management. Based upon that evaluation, MD’s Chief Executive Officer and Chief Financial Officer concluded that its disclosure controls and procedures are effective for gathering, analyzing and disclosing the information the Partnership is required to disclose in the reports it files under the Securities Exchange Act of 1934 within the time periods specified in the SEC’s rules and forms. Since MD’s December 31, 2013 annual report on internal control over financial reporting, and for the quarter ended June 30, 2014, there have been no changes in MD’s internal controls or in other factors which have materially affected, or are reasonably likely to materially affect, the internal controls over financial reporting.

 

 

Part II – Other Information

 

Item 1.  Legal Proceedings

 

From time to time, the Registrant may be a party to certain legal actions and claims arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, the Partnership does not expect these matters to have a material effect on its financial position or results of operations.

 

Item 6.  Exhibits and Reports on Form 8-K

 

		(a)	Exhibits filed herewith.
			31.1	Certification of CEO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
			31.2	Certification of CFO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
			32.1	Certification of CEO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
			32.2	Certification of CFO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
			101	The following materials from the Partnership's Quarterly Report on Form 10-Q for the quarter ended June 30, 2014 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statement of Changes in Partners' Capital, (iv) the Condensed Statements of Cash Flows, and (v) related notes.
		(b)	Reports on Form 8-K
			None.

  

 

SIGNATURES

  

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

 

	Mewbourne Energy Partners 09-A, L.P.
	By:	Mewbourne Development Corporation
		Managing General Partner

 

Date:	August 14, 2014
		By:	/s/ Alan Clark
			Alan Clark, Treasurer and Controller

 

 

INDEX TO EXHIBITS

 

EXHIBIT
NUMBER	DESCRIPTION
31.1	Certification of CEO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
31.2	Certification of CFO Pursuant to Section 302 of Sarbanes-Oxley Act of 2002.
32.1	Certification of CEO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
32.2	Certification of CFO Pursuant to Section 906 of Sarbanes-Oxley Act of 2002.
101	The following materials from the Partnership's Quarterly Report on Form 10-Q for the quarter ended June 30, 2014 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statement of Changes in Partners' Capital, (iv) the Condensed Statements of Cash Flows, and (v) related notes.