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EX-32.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002 - Mewbourne Energy Partners 07-A, L.P.dex321.htm
EX-32.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 906 OF SARBANES-OXLEY ACT OF 2002 - Mewbourne Energy Partners 07-A, L.P.dex322.htm
EX-31.1 - CERTIFICATION OF CEO PURSUANT TO SECTION 302 - Mewbourne Energy Partners 07-A, L.P.dex311.htm
EXCEL - IDEA: XBRL DOCUMENT - Mewbourne Energy Partners 07-A, L.P.Financial_Report.xls
EX-31.2 - CERTIFICATION OF CFO PURSUANT TO SECTION 302 OF SARBANES-OXLEY ACT OF 2002 - Mewbourne Energy Partners 07-A, L.P.dex312.htm
Table of Contents

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, 2011

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. 000-53190

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

 

                             Delaware

    

20-8481823

(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]     No [   ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).Yes  [X]    No [  ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company 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  [   ]    No  [X]


Table of Contents

MEWBOURNE ENERGY PARTNERS 07-A, L.P.

INDEX

 

Part 1  -  Financial Information

     Page No.   

Item 1. Financial Statements

  

Condensed Balance Sheets -
June 30, 2011 (Unaudited) and December 31, 2010

     3   

Condensed Statements of Operations (Unaudited) -
For the three months ended June  30, 2011 and 2010
and the six months ended June 30, 2011 and 2010

     4   

Condensed Statements of Cash Flows (Unaudited) -
For the six months ended June 30, 2011 and 2010

     5   

Condensed Statement of Changes In Partners’ Capital (Unaudited) -
For the six months ended June 30, 2011

     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

     13   

Item 1. Legal Proceedings

     13   

Item 6. Exhibits and Reports on Form 8-K

     13   

 

2


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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

Part I - Financial Information

Item 1. Financial Statements

CONDENSED BALANCE SHEETS

June 30, 2011 and December 31, 2010

 

     June 30, 2011     December 31, 2010  
     (Unaudited)        

ASSETS

    

Cash

   $ 40,979      $ 3,890   

Accounts receivable, affiliate

     1,470,836        1,376,777   

Prepaid state taxes

     12,500        7,500   
  

 

 

   

 

 

 

Total current assets

     1,524,315        1,388,167   
  

 

 

   

 

 

 

Oil and gas properties at cost, full-cost method

     66,086,384        66,048,902   

Less accumulated depreciation, depletion and amortization

     (46,864,763     (46,103,085
  

 

 

   

 

 

 
     19,221,621        19,945,817   
  

 

 

   

 

 

 

Total assets

   $ 20,745,936      $ 21,333,984   
  

 

 

   

 

 

 

LIABILITIES AND PARTNERS’ CAPITAL

    

Accounts payable, affiliate

   $ 182,037      $ 408,731   
  

 

 

   

 

 

 

Total current liabilities

     182,037        408,731   
  

 

 

   

 

 

 

Asset retirement obligation

     417,746        404,165   

Partners’ capital

     20,146,153        20,521,088   
  

 

 

   

 

 

 

Total liabilities and partners’ capital

   $ 20,745,936      $ 21,333,984   
  

 

 

   

 

 

 

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

 

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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

CONDENSED STATEMENTS OF OPERATIONS

For the three months ended June 30, 2011 and 2010 and

the six months ended June 30, 2011 and 2010

(Unaudited)

 

    

Three Months Ended

 

June 30,

 

    

Six Months Ended

 

June 30,

 

 
           2011                  2010                  2011                  2010        

Revenues and other income:

           

  Oil sales

   $ 609,918       $ 779,620       $ 1,237,793       $ 1,624,490   

  Gas sales

     1,571,538         1,912,709         2,843,353         4,471,894   

  Interest income

     -         172         4,479         310   
  

 

 

    

 

 

    

 

 

    

 

 

 

    Total revenues and other income

     2,181,456         2,692,501         4,085,625         6,096,694   
  

 

 

    

 

 

    

 

 

    

 

 

 

Expenses:

           

  Lease operating expense

     204,681         207,623         501,930         621,923   

  Production taxes

     116,415         100,514         189,486         285,554   

  Administrative and general expense

     90,718         138,301         173,866         263,224   

  Depreciation, depletion, and amortization

     410,138         515,078         761,678         1,086,683   

  Asset retirement obligation accretion

     6,956         6,489         13,849         12,948   
  

 

 

    

 

 

    

 

 

    

 

 

 

    Total expenses

     828,908         968,005         1,640,809         2,270,332   
  

 

 

    

 

 

    

 

 

    

 

 

 

  Net income

   $ 1,352,548       $ 1,724,496       $ 2,444,816       $ 3,826,362   
  

 

 

    

 

 

    

 

 

    

 

 

 

  Basic and diluted net income perpartner interest (14,000 interests outstanding)

   $ 96.61       $ 123.18       $ 174.63       $ 273.31   
  

 

 

    

 

 

    

 

 

    

 

 

 

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

 

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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

CONDENSED STATEMENTS OF CASH FLOWS

For the six months ended June 30, 2011 and 2010

(Unaudited)

 

    

Six Months Ended

 

June 30,

 

 
           2011                     2010          

Cash flows from operating activities:

    

Net income

   $ 2,444,816      $ 3,826,362   

Adjustments to reconcile net income to net cash provided by operating activities:

    

Depreciation, depletion, and amortization

     761,678        1,086,683   

Asset retirement obligation accretion

     13,849        12,948   

Changes in operating assets and liabilities:

    

Accounts receivable, affiliate

     (94,059     506,466   

Prepaid state taxes

     (5,000     (2,500

Accounts payable, affiliate

     (226,694     (37,824
  

 

 

   

 

 

 

Net cash provided by operating activities

     2,894,590        5,392,135   
  

 

 

   

 

 

 

Cash flows from investing activities:

    

Purchase and development of oil and gas properties

     (37,750     (368,265
  

 

 

   

 

 

 

Net cash used in investing activities

     (37,750     (368,265
  

 

 

   

 

 

 

Cash flows from financing activities:

    

Cash distributions to partners

     (2,819,751     (5,204,374
  

 

 

   

 

 

 

Net cash used in financing activities

     (2,819,751     (5,204,374
  

 

 

   

 

 

 

Net increase (decrease) in cash and cash equivalents

     37,089        (180,504

Cash and cash equivalents, beginning of period

     3,890        282,559   
  

 

 

   

 

 

 

Cash, end of period

   $ 40,979      $ 102,055   
  

 

 

   

 

 

 

Supplemental Cash Flow Information:

    

Non-cash changes to oil & gas properties related to asset retirement obligation liabilities

   $ (268   $ 4,141   
  

 

 

   

 

 

 

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

 

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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

CONDENSED STATEMENT OF CHANGES IN PARTNERS’ CAPITAL

For the six months ended June 30, 2011

(Unaudited)

 

     Total  

Balance at December 31, 2010

     $         20,521,088     

Cash distributions

     (2,819,751)    

Net income

     2,444,816     
  

 

 

 

Balance at June 30, 2011

     $ 20,146,153     
  

 

 

 

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

 

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MEWBOURNE ENERGY PARTNERS 07-A, L.P.

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

 

1.

Description of Business

Mewbourne Energy Partners 07-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 March 1, 2007. The offering of limited and general partner interests began May 1, 2007 as a part of a private placement pursuant to Section 4(2) of the Securities Act of 1933 and Regulation D promulgated thereunder, as a part of the Mewbourne Energy Partners 07 Drilling Program, (the “Program”), and concluded August 13, 2007 with total investor contributions of $70,000,000 originally being sold to accredited investors, of which $65,710,000 were sold to accredited investors as general partner interests and $4,290,000 were sold to accredited investors as limited partner interests. During 2009, 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 2010, 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, 2011 and 2010, 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 no cost ceiling write-down for the three or six months ended June 30, 2011 or 2010.

 

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4.

Asset Retirement Obligations

The Partnership has recognized an estimated liability for future plugging and abandonment costs. The estimated liability is 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 ownership interests or well plugging and abandonment costs, 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, 2011 and the year ended December 31, 2010 is as follows:

 

         June 30, 2011              December 31, 2010      

Balance, beginning of period

     $ 404,165          $ 374,238    

Liabilities incurred

             4,141    

Liabilities reduced due to revisions

     (268)         (136)   

Accretion expense

     13,849          25,922    
  

 

 

    

 

 

 

Balance, end of period

   $ 417,746        $ 404,165    
  

 

 

    

 

 

 

 

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 .7% 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 general, 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.

 

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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 andadministrative 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 07-A, L.P. (“the Partnership”) was formed March 1, 2007. The offering of limited and general partnership interests began May 1, 2007 and concluded August 13, 2007, with total investor contributions of $70,000,000. During 2009, 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 June 30, 2011, the Registrant owned working interests in one hundred thirteen 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 $1,342,278 at June 30, 2011.

During the six months ended June 30, 2011, the Partnership made cash distributions to the investor partners in the amount of $2,819,751 as compared to $5,204,374 for the six months ended June 30, 2010. The Partnership expects that cash distributions will continue during 2011 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.

 

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Results of Operations

For the three months ended June 30, 2011 as compared to the three months ended June 30, 2010:

 

     Three Months Ended June 30,  
     2011      2010  

Oil sales

     $ 609,918          $ 779,620    

Barrels produced

     6,271          9,346    

Average price/bbl

     $ 97.26          $ 83.42    

Gas sales

     $ 1,571,538          $ 1,912,709    

Mcf produced

     269,610          380,941    

Average price/mcf

     $ 5.83          $ 5.02    

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $510,873, a 19% decrease, for the three months ended June 30, 2011 as compared to the three months ended June 30, 2010.

Of this decrease, $299,075 and $648,941 were due to decreases in the volumes of oil and gas sold, respectively. The volumes sold decreased by 3,075 bbls and 111,331 mcf for the three months ended June 30, 2011 as compared to the three months ended June 30, 2010. The decreases in volumes of oil and gas sold were primarily due to normal declines in production.

Those decreases were partially offset by increases of $129,373 and $307,770 due to increases in the average prices of oil and gas sold, respectively. Average prices rose to $97.26 from $83.42 per bbl and to $5.83 from $5.02 per mcf for the three months ended June 30, 2011 as compared to the three months ended June 30, 2010.

Lease operations. Lease operating expense during the three month period ended June 30, 2011 decreased to $204,681 from $207,623 for the three months ended June 30, 2010.

Production taxes. Production taxes during the three month period ended June 30, 2011 increased to $116,415 from $100,514 for the three month period ended June 30, 2010 due to production tax credits taken in the three month period ended June 30, 2010.

Administrative and general expense. Administrative and general expense for the three month period ended June 30, 2011 decreased to $90,718 from $138,301 for the three month period ended June 30, 2010 due to decreased administrative expenses allocable to the Partnership and lower general expenses for reporting costs.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the three month period ended June 30, 2011 decreased to $410,138 from $515,078 for the three month period ended June 30, 2010 due to the decreased production volumes for the three month period ended June 30, 2011.

 

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Results of Operations

For the six months ended June 30, 2011 as compared to the six months ended June 30, 2010:

 

     Six Months Ended June 30,  
     2011      2010  

Oil sales

     $ 1,237,793          $ 1,624,490    

Barrels produced

     13,234          21,071    

Average price/bbl

     $ 93.53          $ 77.10    

Gas sales

     $ 2,843,353          $ 4,471,894    

Mcf produced

     503,699          791,430    

Average price/mcf

     $ 5.64          $ 5.65    

Oil and gas revenues. As shown in the above table, total oil and gas sales decreased by $2,015,238, a 33.1 % decrease, for the six months ended June 30, 2011 as compared to the six months ended June 30, 2010.

Of this decrease, $733,005 and $1,624,226 were due to decreases in the volumes of oil and gas sold, respectively. The volumes sold decreased by 7,837 bbls and 287,731 mcf for the six months ended June 30, 2011 as compared to the six months ended June 30, 2010. The decreases in volumes of oil and gas sold were primarily due to normal declines in production.

Also included in this decrease was $4,315 was due to a decrease in the average price of gas sold. The average price fell to $5.64 from $5.65 per mcf for the six months ended June 30, 2011 as compared to the six months ended June 30, 2010.

Those decreases were partially offset by an increase in revenue of $346,308 due to an increase in the average price of oil sold to $93.53 from $77.10 per bbl for the six months ended June 30, 2011 as compared to the six months ended June 30, 2010.

Lease operations. Lease operating expense during the six month period ended June 30, 2011 decreased to $501,930 from $621,923 for the six months ended June 30, 2010 due to fewer well repairs and workovers in the six month period ended June 30, 2011.

Production taxes. Production taxes during the six month period ended June 30, 2011 decreased to $189,486 from $285,554 for the six month period ended June 30, 2010 due to lower overall oil and gas revenue.

Administrative and general expense. Administrative and general expense for the six month period ended June 30, 2011 decreased to $173,866 from $263,224 for the six month period ended June 30, 2010 due to decreased administrative expenses allocable to the Partnership and lower general expenses for reporting costs.

Depreciation, depletion and amortization. Depreciation, depletion and amortization for the six month period ended June 30, 2011 decreased to $761,678 from $1,086,683 for the six month period ended June 30, 2010 due to the decreased production volumes for the six month period ended June 30, 2011.

 

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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, 2011, a 10% change in the price received for natural gas production would have had an approximate $284,000 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, 2010 annual report on internal control over financial reporting, and for the quarter ended June 30, 2011, 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.

 

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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, 2011 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.

 

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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 07-A, L.P.
 

By:

 

Mewbourne Development Corporation

   

Managing General Partner

Date:               August 15, 2011

 

 

By:

 

/s/ Alan Clark

   

Alan Clark, Treasurer and Controller

 

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Table of Contents

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, 2011 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.