Mewbourne Energy Partners 10-A, L.P. - FORM 10-Q

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EXCEL - IDEA: XBRL DOCUMENT - Mewbourne Energy Partners 10-A, L.P.	Financial_Report.xls
EX-31.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 302 OF SARBANES-OXLEY ACT OF 2002. - Mewbourne Energy Partners 10-A, L.P.	ex-31_1.htm
EX-32.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002. - Mewbourne Energy Partners 10-A, L.P.	ex-32_2.htm
EX-32.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002. - Mewbourne Energy Partners 10-A, L.P.	ex-32_1.htm
EX-31.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 302 OF SARBANES-OXLEY ACT OF 2002. - Mewbourne Energy Partners 10-A, L.P.	ex-31_2.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2012

o 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. 000-54370

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

Delaware		27-1903816
(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 x Noo

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 o

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	¨	Smaller reporting company	x
Do not check if 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 o No x

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

INDEX

Part 1 - Financial Information				Page No.

	Item 1. Financial Statements

		Condensed Balance Sheets -
			September 30, 2012 (Unaudited) and December 31, 2011	3

		Condensed Statements of Operations (Unaudited) -
			For the three months ended September 30, 2012 and 2011
			and the nine months months ended September 30, 2012 and 2011	4

		Condensed Statements of Cash Flows (Unaudited) -
			For the nine months ended September 30, 2012 and 2011	5

		Condensed Statement of Changes In Partners' Capital (Unaudited) -
			For the nine months ended September 30, 2012	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 10-A, L.P.

Part I - Financial Information

Item 1. Financial Statements
CONDENSED BALANCE SHEETS


	September 30, 2012			December 31, 2011
	(Unaudited)
ASSETS

Cash and cash equivalents	$	789,496		$	3,088,905
Accounts receivable, affiliate		2,721,829			6,674,611
Prepaid state taxes		5,000			—
Total current assets		3,516,325			9,763,516

Oil and gas properties at cost, full-cost method		68,509,624			67,436,645
Less accumulated depreciation, depletion,
amortization and impairment		(22,914,620	)		(11,331,072	)
		45,595,004			56,105,573

Total assets	$	49,111,329		$	65,869,089


LIABILITIES AND PARTNERS' CAPITAL

Accounts payable, affiliate	$	324,814		$	347,971
Total current liabilities		324,814			347,971

Asset retirement obligation		723,230			694,291

Partners' capital
General partners		—			60,226,787
Limited partners		48,063,285			4,600,040
Total partners' capital		48,063,285			64,826,827

Total liabilities and partners' capital	$	49,111,329		$	65,869,089

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

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS
(Unaudited)

	For the					For the
	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2012			2011		2012		2011
Revenues and other income:
Oil sales	$	2,714,481		$	8,941,499	$	11,125,967	$	19,838,246
Gas sales		1,163,831			4,488,510		4,525,913		8,552,516
Interest income		7			1,811		365		17,014
Total revenues and other income		3,878,319			13,431,820		15,652,245		28,407,776

Expenses:
Lease operating expense		350,579			450,848		1,143,593		906,877
Production taxes		105,902			923,928		624,209		1,741,272
Administrative and general expense		44,689			382,768		692,536		612,627
Depreciation, depletion, and amortization		1,488,655			4,115,813		5,473,885		8,114,309
Cost ceiling write-down		4,354,840			—		6,109,663		—
Asset retirement obligation accretion		7,314			6,017		21,900		13,446
Total expenses		6,351,979			5,879,374		14,065,786		11,388,531

Net income (loss)	$	(2,473,660	)	$	7,552,446	$	1,586,459	$	17,019,245
Allocation of net income (loss):
General partners	$	—		$	7,016,533	$	—	$	15,811,578
Limited partners	$	(2,473,660	)	$	535,913	$	1,586,459	$	1,207,667

Basic and diluted net income (loss) per
partner interest
(14,600 interests outstanding)	$	(169.43	)	$	517.29	$	108.66	$	1,165.70

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

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)

	For the
	Nine Months Ended
	September 30,
	2012			2011
Cash flows from operating activities:
Net income	$	1,586,459		$	17,019,245
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		5,473,885			8,114,309
Cost ceiling write-down		6,109,663			-
Asset retirement obligation accretion		21,900			13,446
Changes in operating assets and liabilities:
Accounts receivable, affiliate		3,952,782			(7,677,759	)
Prepaid state taxes		(5,000	)		—
Accounts payable, affiliate		(23,157	)		5,625,605
Net cash provided by operating activities		17,116,532			23,094,846

Cash flows from investing activities:
Purchase and development of oil and gas properties		(1,065,940	)		(53,025,785	)
Net cash used in investing activities		(1,065,940	)		(53,025,785	)

Cash flows from financing activities:
Cash distributions to partners		(18,350,001	)		(15,450,000	)
Net cash used in financing activities		(18,350,001	)		(15,450,000	)

Net decrease in cash		(2,299,409	)		(45,380,939	)
Cash and cash equivalents, beginning of period		3,088,905			51,109,051

Cash and cash equivalents, end of period	$	789,496		$	5,728,112

Supplemental Cash Flow Information:
Non-cash changes to net oil & gas properties related to
asset retirement obligation liabilities	$	7,039		$	569,581

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

							Total
	General			Limited			Partners'
	Partners			Partners			Capital

Balance at December 31, 2011	$	60,226,787		$	4,600,040		$	64,826,827

Conversion of general partner
interests to limited partner interests		(60,226,787	)		60,226,787			—

Cash distributions		—			(18,350,001	)		(18,350,001	)
Net income		—			1,586,459			1,586,459

Balance at September 30, 2012	$	—		$	48,063,285		$	48,063,285

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

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1. Description of Business

Mewbourne Energy Partners 10-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 9, 2010. The offering of limited and general partner interests began May 1, 2010 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 2, 2010, with total investor contributions of $73,000,000 originally being sold to accredited investors of which $67,820,000 were sold to accredited investors as general partner interests and $5,180,000 were sold to accredited investors as limited partner interests. During the first quarter of 2012, 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 2011, 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 September 30, 2012 all capitalized costs were subject to amortization, while at September 30, 2011 approximately $1.6 million of development in progress capitalized costs were excluded from 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 were cost ceiling write-downs at June 30, 2012 of $1,754,823 and at September 30, 2012 of $4,354,840 for a total of $6,109,663 during 2012. These were due to decreased gas prices. There were no cost ceiling write-downs during the nine months ended September 30, 2011.

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 nine months ended September 30, 2012 and the year ended December 31, 2011 is as follows:

	September 30,			December 31,
	2012			2011
Balance, beginning of period	$	694,291		$	89,972
Liabilities incurred		16,169			584,675
Liabilities reduced due to revisions		(9,130	)		—
Accretion expense		21,900			19,644
Balance, end of period	$	723,230		$	694,291

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 consideration for services rendered by MD in managing the business of the Partnership, the Partnership during each of the initial three years of the Partnership will pay to MD a management fee in the amount equal to .75% of the subscriptions by the investor partners to the Partnership. The Partnership will include the management fee as part of the full cost pool pursuant to 4-10(c)(2) of Regulation S-X.

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	%
Reporting and legal expenses		100	%		0	%
Operating costs, general and administrative expenses (except for
reporting and legal 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 10-A, L.P. (“the Partnership”) was formed February 9, 2010. The offering of limited and general partnership interests began May 1, 2010 and concluded August 2, 2010, with total investor contributions of $73,000,000. During 2012, all general partner equity interests were converted to limited partner equity interests.

The Registrant owns fractional working interests in developmental oil and gas prospects, which has resulted in participation in the drilling of oil and gas wells. At September 30, 2012, the Registrant owned working interests in 98 producing wells.

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 $3,191,511 at September 30, 2012.

During the nine months ended September 30, 2012, the Partnership made cash distributions to the investor partners in the amount of $18,350,001 as compared to $15,450,000 for the nine months ended September 30, 2011. The Partnership expects that cash distributions will continue during 2012 as additional oil and gas revenues are sufficient to produce cash flows from operations.

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 September 30, 2012 as compared to the three months ended September 30, 2011:


	Three Months Ended September 30,
	2012		2011
Oil sales	$	2,714,481	$	8,941,499
Barrels produced		30,704		107,784
Average price/bbl	$	88.41	$	82.96

Gas sales	$	1,163,831	$	4,488,510
Mcf produced		285,972		627,977
Average price/mcf	$	4.07	$	7.15

Oil and gas revenues. As shown in the above table, total oil and gas sales fell by $9,551,697, a 71.1% decrease, for the three months ended September 30, 2012 as compared to the three months ended September 30, 2011.

Of this decline, $6,814,493 and $1,391,871 were due to decreases in the volumes of oil and gas sold, respectively. The volumes sold decreased by 77,080 barrels (bbls) and 342,005 thousand cubic feet (mcf) for the three months ended September 30, 2012 as compared to the three months ended September 30, 2011. The decreases in volumes of oil and gas sold were primarily due to normal declines in production, which in some wells were substantial.

Also contributing to the decrease in revenue was $1,932,808 due to a decrease in the average price of gas sold. The average price fell to $4.07 from $7.15 per mcf for the three months ended September 30, 2012 as compared to the three months ended September 30, 2011.

These declines were partially offset by $587,475 due to an increase in the average price of oil sold. The average price rose to $88.41 from $82.96 per bbl for the three months ended September 30, 2012 as compared to the three months ended September 30, 2011.

Lease operations. Lease operating expense during the three month period ended September 30, 2012 fell to $350,579 from $450,848 for the three month period ended September 30, 2011 due to fewer well repairs and workovers.

Production taxes. Production taxes during the three month period ended September 30, 2012 decreased to $105,902 from $923,928 for the three month period ended September 30, 2011 due to lower overall oil and gas revenue and production tax credits.

Administrative and general expense. Administrative and general expense for the three month period ended September 30, 2012 decreased to $44,689 from $382,768 for the three month period ended September 30, 2011 due to decreased administrative expenses allocable to the Partnership.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended September 30, 2012 decreased to $1,488,655 from $4,115,813 for the three month period ended September 30, 2011 due to the decreased production volumes for the three month period ended September 30, 2012.

Cost ceiling write-down. There was a cost ceiling write-down of $4,354,840 at September 30, 2012 due to lower oil and gas prices. There was no cost ceiling write-down for the three months ended September 30, 2011.

Results of Operations

For the nine months ended September 30, 2012 as compared to the nine months ended September 30, 2011:

	Nine Months Ended September 30,
	2012		2011
Oil sales	$	11,125,967	$	19,838,246
Barrels produced		120,220		221,769
Average price/bbl	$	92.55	$	89.45

Gas sales	$	4,525,913	$	8,552,516
Mcf produced		995,737		1,252,189
Average price/mcf	$	4.55	$	6.83

Oil and gas revenues. As shown in the above table, total oil and gas sales fell by $12,738,882, a 44.9% decrease, for the nine months ended September 30, 2012 as compared to the nine months ended September 30, 2011.

Of this decline, $9,398,027 and $1,165,649 were due to decreases in the volumes of oil and gas sold, respectively. The volumes sold decreased by 101,549 barrels (bbls) and 256,452 thousand cubic feet (mcf) for the nine months ended September 30, 2012 as compared to the nine months ended September 30, 2011. The decreases in volumes of oil and gas sold were primarily due to normal declines in production, which in some wells were substantial.

Also contributing to the decrease in revenue was $2,860,954 due to a decrease in the average price of gas sold. The average price fell to $4.55 from $6.83 per mcf for the nine months ended September 30, 2012 as compared to the nine months ended September 30, 2011.

These declines were partially offset by $685,748 due to an increase in the average price of oil sold. The average price rose to $92.55 from $89.45 per bbl for the nine months ended September 30, 2012 as compared to the nine months ended September 30, 2011.

Lease operations. Lease operating expense during the nine month period ended September 30, 2012 increased to $1,143,593 from $906,877 for the nine month period ended September 30, 2011 due to more workovers and repairs.

Production taxes. Production taxes during the nine month period ended September 30, 2012 decreased to $624,209 from $1,741,272 for the nine month period ended September 30, 2011 due to lower overall oil and gas revenue and production tax credits.

Administrative and general expense. Administrative and general expense for the nine month period ended September 30, 2012 increased to $692,536 from $612,627 for the nine month period ended September 30, 2011 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 nine month period ended September 30, 2012 decreased to $5,473,885 from $8,114,309 for the nine month period ended September 30, 2011 due to the decreased production volumes for the nine month period ended September 30, 2012.

Cost ceiling write-down. There were cost ceiling write-downs at June 30, 2012 of $1,754,823 and at September 30, 2012 of $4,354,840 for a total of $6,109,663 during 2012. These were due to decreased gas prices. There were no cost ceiling write-downs during the nine month period ended September 30, 2011.

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 nine months ended September 30, 2012, a 10% change in the price received for oil and gas production would have had an approximate $1,565,000 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, 2011 annual report on internal control over financial reporting, and for the quarter ended September 30, 2012, 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 September 30, 2012 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statements of Cash Flows, (iv) the Condensed Statement of Changes in Partners’ Capital 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 10-A, L.P.

		By:	Mewbourne Development Corporation
			Managing General Partner

Date: November 14, 2012		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 September 30, 2012 formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Balance Sheets, (ii) the Condensed Statements of Operations, (iii) the Condensed Statements of Cash Flows, (iv) the Condensed Statement of Changes in Partners’ Capital and (v) related notes.

MEWBOURNE ENERGY PARTNERS 10-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL

For the nine months ended September 30, 2012

(Unaudited)