MEWBOURNE ENERGY PARTNERS 01-A LP - FORM 10-Q

Attached files

file	filename
EXCEL - IDEA: XBRL DOCUMENT - MEWBOURNE ENERGY PARTNERS 01-A LP	Financial_Report.xls
EX-31.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 302 OF SARBANES-OXLEY ACT OF 2002. - MEWBOURNE ENERGY PARTNERS 01-A LP	ex-31_2.htm
EX-32.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002. - MEWBOURNE ENERGY PARTNERS 01-A LP	ex-32_1.htm
EX-31.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 302 OF SARBANES-OXLEY ACT OF 2002. - MEWBOURNE ENERGY PARTNERS 01-A LP	ex-31_1.htm
EX-32.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002. - MEWBOURNE ENERGY PARTNERS 01-A LP	ex-32_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 June 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. 333-57156

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

Delaware		75-2926279
(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 01-A, L.P.

INDEX

Part 1 - Financial Information				Page No.

	Item 1. Financial Statements

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

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

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

		Condensed Statement of Changes In Partners' Capital (Unaudited) -
			For the six months ended June 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 01-A, L.P.
Part I - Financial Information

Item 1. Financial Statements
CONDENSED BALANCE SHEETS

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

Cash	$	60		$	4,947
Accounts receivable, affiliate		128,575			130,894
Prepaid state taxes		466			1,867
Total current assets		129,101			137,708

Oil and gas properties at cost, full-cost method		15,504,332			15,485,787
Less accumulated depreciation, depletion,
amortization and impairment		(13,922,245	)		(13,871,051	)
		1,582,087			1,614,736

Total assets	$	1,711,188		$	1,752,444


LIABILITIES AND PARTNERS' CAPITAL

Accounts payable, affiliate	$	51,351		$	33,010
Total current liabilities		51,351			33,010

Asset retirement obligation		412,795			395,401

Partners' capital		1,247,042			1,324,033

Total liabilities and partners' capital	$	1,711,188		$	1,752,444

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

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS
(Unaudited)

	For the				For the
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2012		2011		2012		2011
Revenues and other income:
Oil sales	$	75,418	$	23,834	$	105,512	$	33,242
Gas sales		134,848		182,082		238,968		320,093
Interest income		-		-		-		642
Total revenues and other income		210,266		205,916		344,480		353,977

Expenses:
Lease operating expense		68,095		65,666		233,196		139,990
Production taxes		13,453		14,026		22,506		24,708
Administrative and general expense		18,902		18,734		28,310		25,621
Depreciation, depletion, and amortization		31,055		21,444		51,194		38,236
Asset retirement obligation accretion		3,783		3,547		7,525		7,094
Total expenses		135,288		123,417		342,731		235,649

Net income	$	74,978	$	82,499	$	1,749	$	118,328

Basic and diluted net income per
partner interest
(15,000 interests outstanding)	$	5.00	$	5.50	$	0.12	$	7.89

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

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
	For the
	Six Months Ended
	June 30,
	2012			2011
Cash flows from operating activities:
Net income	$	1,749		$	118,328
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		51,194			38,236
Asset retirement obligation accretion		7,525			7,094
Changes in operating assets and liabilities:
Accounts receivable, affiliate		2,319			(21,514	)
Prepaid state taxes		1,401			(931	)
Accounts payable, affiliate		18,341			8,047
Net cash provided by operating activities		82,529			149,260

Cash flows from investing activities:
Purchase and development of oil and gas properties		(8,676	)		(2,717	)
Net cash used in investing activities		(8,676	)		(2,717	)

Cash flows from financing activities:
Cash distributions to partners		(78,740	)		(142,315	)
Net cash used in financing activities		(78,740	)		(142,315	)

Net increase (decrease) in cash		(4,887	)		4,228
Cash, beginning of period		4,947			787

Cash, end of period	$	60		$	5,015

Supplemental Cash Flow Information:
Non-cash changes to net oil & gas properties related to
asset retirement obligation liabilities	$	9,869		$	-

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

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL
For the six months ended June 30, 2012
(Unaudited)



	Partners' Capital

Balance at December 31, 2011	$	1,324,033

Cash distributions		(78,740	)

Net income		1,749

Balance at June 30, 2012	$	1,247,042

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

MEWBOURNE ENERGY PARTNERS 01-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1. Description of Business

Mewbourne Energy Partners 01-A, L.P. (the “Registrant” or the “Partnership”), a Delaware limited partnership, is engaged primarily in oil and gas development and production in Texas, Oklahoma, and New Mexico, and was organized on February 23, 2001. The offering of limited and general partnership interests began June 12, 2001 as a part of an offering registered under the name Mewbourne Energy Partners 01-02 Drilling Program, (the “Program”), and concluded August 28, 2001, with total investor contributions of $15,000,000 originally being sold to 569 subscribers of which $13,513,000 were sold to 528 subscribers as general partner interests and $1,487,000 were sold to 41 subscribers as limited partner interests. During 2003, 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 June 30, 2012 and 2011, 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 were no cost ceiling write-downs for the six months ended June 30, 2012 or 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 six months ended June 30, 2012 and the year ended December 31, 2011 is as follows:

	June 30,		December 31,
	2012		2011
Balance, begining of period	$	395,401	$	381,223
Liabilities incurred		9,869		-
Accretion expense		7,525		14,178
Balance, end of period	$	412,795	$	395,401

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		60	%		40	%
All other revenues		60	%		40	%

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		60	%		40	%

(1)

Pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 30% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 30% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 30%. 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 01-A, L.P. was formed February 23, 2001. The offering of limited and general partnership interests began June 12, 2001 and concluded August 28, 2001, with total investor contributions of $15,000,000. During 2003, 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 $77,750 at June 30, 2012.

During the six months ended June 30, 2012, the Partnership made cash distributions to the investor partners in the amount of $78,740 as compared to $142,315 for the six months ended June 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 June 30, 2012 as compared to the three months ended June 30, 2011:

	Three Months Ended June 30,
	2012		2011
Oil sales	$	75,418	$	23,834
Barrels produced		860		236
Average price/bbl	$	87.70	$	100.99

Gas sales	$	134,848	$	182,082
Mcf produced		48,306		43,028
Average price/mcf	$	2.79	$	4.23

Oil and gas revenues. As shown in the above table, total oil and gas sales rose by $4,350, a 2.1% increase, for the three months ended June 30, 2012 as compared to the three months ended June 30, 2011.

Of this increase, $54,722 and $14,734 were due to increases in the volumes of oil and gas sold, respectively. The volumes sold increased by 624 barrels (bbls) and 5,278 thousand cubic feet (mcf) for the three months ended June 30, 2012 as compared to the three months ended June 30, 2011. The increases in volumes were primarily due to farmouts in four wells which paid out in 2012. Now that these wells have been paid out, the Partnership will have an interest in the production and revenue of the wells in the future.

These increases were partially offset by $3,138 and $61,968 from declines in the average prices of oil and gas sold, respectively. The average prices fell to $87.70 from $100.99 per bbl and to $2.79 from $4.23 per mcf for the three months ended June 30, 2012 as compared to the three months ended June 30, 2011.

Lease operations. Lease operating expense during the three month period ended June 30, 2012 increased to $68,095 from $65,666 for the three month period ended June 30, 2011 due to more well repairs and workovers.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended June 30, 2012 increased to $31,055 from $21,444 for the three month period ended June 30, 2011 due to the increased production volumes for the three month period ended June 30, 2012.

Results of Operations

For the six months ended June 30, 2012 as compared to the six months ended June 30, 2011:

	Six Months Months Ended June 30,
	2012		2011
Oil sales	$	105,512	$	33,242
Barrels produced		1,164		345
Average price/bbl	$	90.65	$	96.35

Gas sales	$	238,968	$	320,093
Mcf produced		86,092		74,759
Average price/mcf	$	2.78	$	4.28

Oil and gas revenues. As shown in the above table, total oil and gas sales fell by $8,855, a 2.5% decrease, for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011.

Of this decrease, $1,969 and $112,582 were due to declines in the average prices of oil and gas sold, respectively. The average prices fell to $90.65 from $96.35 per barrel (bbl) and to $2.78 from $4.28 per thousand cubic feet (mcf) for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011.

These decreases were partially offset by $74,239 and $31,457 due to increases in the volumes of oil and gas sold, respectively. The volumes sold increased by 819 bbls and 11,333 mcf for the six months ended June 30, 2012 as compared to the six months ended June 30, 2011. The increases in volumes were primarily due to farmouts in four wells which paid out in 2012.

Lease operations. Lease operating expense during the six month period ended June 30, 2012 increased to $233,196 from $139,990 for the six month period ended June 30, 2011 due to more well repairs and workovers.

Administrative and general expenses. Administrative and general expenses increased to $28,310 for the six months ended June 30, 2012 from $25,621 for the six months ended June 30, 2011 due to increased administrative expenses allocable to the Partnership and higher legal and reporting costs.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six month period ended June 30, 2012 increased to $51,194 from $38,236 for the six month period ended June 30, 2011 due to the increased production volumes for the six month period ended June 30, 2012.

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, 2012, a 10% change in the price received for oil and gas production would have had an approximate $34,000 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 June 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 June 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 01-A, L.P.

		By:	Mewbourne Development Corporation
			Managing General Partner

Date: August 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 June 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 01-A LP - FORM 10-Q - August 14, 2012

Attached files

MEWBOURNE ENERGY PARTNERS 01-A LP Reports