Mewbourne Energy Partners 06-A, L.P. - FORM 10-Q

Attached files

file	filename
EX-31.1 - CERTIFICATION OF CHIEF EXECUTIVE OFFICER - Mewbourne Energy Partners 06-A, L.P.	ex-31_1.htm
EX-31.2 - CERTIFICATION OF CHIEF FINANCIAL OFFICER - Mewbourne Energy Partners 06-A, L.P.	ex-31_2.htm
EX-32.2 - CERTIFICATION OF CHIEF FINANCIAL OFFICER - Mewbourne Energy Partners 06-A, L.P.	ex-32_2.htm
EXCEL - IDEA: XBRL DOCUMENT - Mewbourne Energy Partners 06-A, L.P.	Financial_Report.xls
EX-32.1 - CERTIFICATION OF CHIEF EXECUTIVE OFFICER - Mewbourne Energy Partners 06-A, L.P.	ex-32_1.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, 2013

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. 333-131978

MEWBOURNE ENERGY PARTNERS 06-A, L.P.

Delaware		20-3791421
(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	¨	(Do not check if a smaller reporting company)	Smaller reporting company	x

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 06-A, L.P.

INDEX

Part 1 - Financial Information				Page No.

	Item 1. Financial Statements

		Condensed Balance Sheets -
			June 30, 2013 (Unaudited) and December 31, 2012	3

		Condensed Statements of Operations (Unaudited) -
			For the three months ended June 30, 2013 and 2012
			and the six months months ended June 30, 2013 and 2012	4

		Condensed Statement of Changes In Partners' Capital (Unaudited) -
			For the six months ended June 30, 2013	5

		Condensed Statements of Cash Flows (Unaudited) -
			For the six months ended June 30, 2013 and 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 06-A, L.P.

Part I - Financial Information

Item 1. Financial Statements
CONDENSED BALANCE SHEETS

	June 30, 2013			December 31, 2012
	(Unaudited)
ASSETS

Cash	$	7,877		$	64,795
Accounts receivable, affiliate		611,389			523,259
Prepaid state taxes		12,500			7,500
Total current assets		631,766			595,554

Oil and gas properties at cost, full-cost method		47,324,509			47,326,152
Less accumulated depreciation, depletion,
amortization and impairment		(39,408,527	)		(39,123,070	)
		7,915,982			8,203,082

Total assets	$	8,547,748		$	8,798,636


LIABILITIES AND PARTNERS' CAPITAL

Accounts payable, affiliate	$	114,933		$	82,155
Total current liabilities		114,933			82,155

Asset retirement obligation		238,085			234,419

Partners' capital		8,194,730			8,482,062

Total liabilities and partners' capital	$	8,547,748		$	8,798,636

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

MEWBOURNE ENERGY PARTNERS 06-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS
(Unaudited)

	For the				For the
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Revenues:
Oil sales	$	305,126	$	261,093	$	499,439	$	574,975
Gas sales		689,787		438,351		1,220,819		932,884
Total revenues		994,913		699,444		1,720,258		1,507,859

Expenses:
Lease operating expense		151,911		133,341		309,658		281,956
Production taxes		56,778		42,500		99,620		92,269
Administrative and general expense		43,904		48,408		82,138		89,683
Depreciation, depletion, and amortization		149,354		183,824		294,804		343,559
Asset retirement obligation accretion		4,144		3,939		8,302		7,958
Total expenses		406,091		412,012		794,522		815,425

Net income	$	588,822	$	287,432	$	925,736	$	692,434

Basic and diluted net income per
partner interest
(50,000 interests outstanding)	$	11.78	$	5.75	$	18.51	$	13.85

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

MEWBOURNE ENERGY PARTNERS 06-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS' CAPITAL
For the six months ended June 30, 2013
(Unaudited)

	Total

Balance at December 31, 2012	$	8,482,062

Cash distributions		(1,213,068	)

Net income		925,736

Balance at June 30, 2013	$	8,194,730

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

MEWBOURNE ENERGY PARTNERS 06-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)

	Six Months Ended
	June 30,
	2013			2012
Cash flows from operating activities:
Net income	$	925,736		$	692,434
Adjustments to reconcile net income to net cash
provided by operating activities:
Depreciation, depletion, and amortization		294,804			343,559
Asset retirement obligation accretion		8,302			7,958
Plugging and abandonment cost paid from asset retirement obligation		(10,851	)		-
Changes in operating assets and liabilities:
Accounts receivable, affiliate		(88,130	)		165,690
Prepaid state taxes		(5,000	)		9,626
Accounts payable, affiliate		32,778			4,807
Net cash provided by operating activities		1,157,639			1,224,074

Cash flows from investing activities:
Purchase and development of oil and gas properties		(1,489	)		(2,594	)
Net cash used in investing activities		(1,489	)		(2,594	)

Cash flows from financing activities:
Cash distributions to partners		(1,213,068	)		(1,232,903	)
Net cash used in financing activities		(1,213,068	)		(1,232,903	)

Net decrease in cash		(56,918	)		(11,423	)
Cash, beginning of period		64,795			11,557

Cash, end of period	$	7,877		$	134

Supplemental Cash Flow Information:
Non-cash changes to net oil & gas properties related to
asset retirement obligation liabilities	$	6,215		$	1,713

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

MEWBOURNE ENERGY PARTNERS 06-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

1. Description of Business

Mewbourne Energy Partners 06-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 November 16, 2005. The offering of limited and general partnership interests began July 11, 2006 as a part of an offering registered under the name Mewbourne Energy Partners 06-07 Drilling Program, (the “Program”), and concluded September 1, 2006, with total investor contributions of $50,000,000 originally being sold to 1,576 subscribers of which $43,174,000 were sold to 1,342 subscribers as general partner interests and $6,826,000 were sold to 234 subscribers as limited partner interests. During, 2008, 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 2012, 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, 2013 and 2012, 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, 2013 or 2012.

4. Asset Retirement Obligations

The Partnership has recognized an estimated asset retirement obligation liability (ARO) 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, 2013 and the year ended December 31, 2012 is as follows:

	June 30,			December 31,
	2013			2012
Balance, beginning of period	$	234,419		$	216,870
Liabilities incurred		7			1,713
Liabilities reduced due to plugging and abandonments		(4,643	)		—
Accretion expense		8,302			15,836
Balance, end of period	$	238,085		$	234,419

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		70	%		30	%
All other revenues		70	%		30	%
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		70	%		30	%

(1)

Pursuant to the Program, MD must contribute 100% of organization and offering costs and lease acquisition costs which should approximate 20% of total capital costs. To the extent that organization and offering costs and lease acquisition costs are less than 20% of total capital costs, MD is responsible for tangible drilling costs until its share of the Program’s total capital costs reaches approximately 20%. 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 06-A, L.P. (the “Partnership”) was formed November 16, 2005. The offering of limited and general partnership interests began July 11, 2006 and concluded September 1, 2006, with total investor contributions of $50,000,000. During 2008, 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 $516,833 at June 30, 2013.

During the six months ended June 30, 2013, the Partnership made cash distributions to the investor partners in the amount of $1,213,068 as compared to $1,232,903 for the six months ended June 30, 2012. The Partnership expects that cash distributions will continue during 2013 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, 2013 as compared to the three months ended June 30, 2012:

	Three Months Ended June 30,
	2013		2012
Oil sales	$	305,126	$	261,093
Barrels produced		3,347		3,001
Average price/bbl	$	91.16	$	87.00

Gas sales	$	689,787	$	438,351
Mcf produced		145,139		164,213
Average price/mcf	$	4.75	$	2.67

Oil and gas revenues. As shown in the above table, total oil and gas sales increased by $295,469, a 42.2% increase, for the three months ended June 30, 2013 as compared to the three months ended June 30, 2012.

Of this increase, $12,490 and $342,087 were due to a rise in the average prices of oil and gas sold, respectively. The average price increased to $91.16 from $87.00 per barrel (bbl) and to $4.75 from $2.67 per thousand cubic feet (mcf) for the three months ended June 30, 2013 as compared to the three months ended June 30, 2012.

Also contributing to the increase was $31,543 due to an increase in the volume of oil sold. Volumes rose by 346 bbls for the three months ended June 30, 2013 as compared to the three months ended June 30, 2012.

These increases were partially offset by a decrease of $90,651 from a decline in the volume of gas sold. Volumes fell by 19,074 mcf for the three months ended June 30, 2013 as compared to the three months ended June 30, 2012.

Lease operations. Lease operating expense during the three month period ended June 30, 2013 increased to $151,911 from $133,341 for the three month period ended June 30, 2012 due to more well repairs and workovers.

Production taxes. Production taxes during the three month period ended June 30, 2013 increased to $56,778 from $42,500 for the three month period ended June 30, 2012 due to higher overall oil and gas revenue.

Administrative and general expense. Administrative and general expense decreased to $43,904 for the three month period ended June 30, 2013 from $48,408 for the three month period ended June 30, 2012 due to decreased administrative expenses allocable to the Partnership.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended June 30, 2013 decreased to $149,354 from $183,824 for the three month period ended June 30, 2012 due to decreased gas production volumes.

Results of Operations

For the six months ended June 30, 2013 as compared to the six months ended June 30, 2012:

	Six Months Ended June 30,
	2013		2012
Oil sales	$	499,439	$	574,975
Barrels produced		5,665		6,173
Average price/bbl	$	88.16	$	93.14

Gas sales	$	1,220,819	$	932,884
Mcf produced		282,433		320,228
Average price/mcf	$	4.32	$	2.91

Oil and gas revenues. As shown in the above table, total oil and gas sales rose by $212,399, a 14.1% increase, for the six months ended June 30, 2013 as compared to the six months ended June 30, 2012.

Of this increase, $451,304 was due to a increase in the average price of gas sold. The average price rose to $4.32 from $2.91 per thousand cubic feet (mcf) for the six months ended June 30, 2013 as compared to the six months ended June 30, 2012.

This increase was partially offset by decreases of $44,786 and $163,369 in the volume of oil and gas sold, respectively. The volume fell by 508 bbls and 37,795 mcf in the six months ended June 30, 2013 as compared to the six months ended June 30, 2012.

Also partially offsetting the rise in sales was $30,750 due to a decrease in the average price of oil sold. The average price of oil fell to $88.16 from $93.14 for the six months ended June 30, 2013 as compared to the six months ended June 30, 2012.

Lease operations. Lease operating expense during the six month period ended June 30, 2013 increased to $309,658 from $281,956 for the six month period ended June 30, 2012 due to more well repairs and workovers.

Production taxes. Production taxes during the six month period ended June 30, 2013 increased to $99,620 from $92,269 for the six month period ended June 30, 2012 due to higher gas revenue.

Administrative and general expense. Administrative and general expense decreased to $82,138 for the six month period ended June 30, 2013 from $89,683 for the six month period ended June 30, 2012 due to decreased administrative expenses allocable to the Partnership.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six month period ended June 30, 2013 decreased to $294,804 from $343,559 for the six month period ended June 30, 2012 due to decreased oil and gas production volumes.

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, 2013, a 10% change in the price received for oil and gas production would have had an approximate $172,000 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, 2012 annual report on internal control over financial reporting, and for the quarter ended June 30, 2013, 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, 2013 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 06-A, L.P.

		By:	Mewbourne Development Corporation
			Managing General Partner

Date: August 14, 2013

		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, 2013 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 06-A, L.P. - FORM 10-Q - August 14, 2013

Attached files

Mewbourne Energy Partners 06-A, L.P. Reports