ITEM 1. Business
Mewbourne Energy Partners 03-A, L.P. (the “Registrant” or the “Partnership”) is a limited partnership organized under the laws of the State of Delaware on February 19, 2003 (date of inception). Mewbourne Development Corporation (“MD”), a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no equity interest in the Registrant.
A Registration Statement was filed pursuant to the Securities Act of 1933, as amended, registering limited and general partnership interests in a series of two Delaware limited partnerships formed under Mewbourne Energy 02-03 Drilling Programs. General and limited partnership interests were offered at $1,000 each. The maximum offering amount was $18,000,000 (18,000 interests) per partnership. The Registration Statement was declared effective by the Securities and Exchange Commission on May 16, 2003. On July 9, 2003, the offering of limited and general partnership interests in the Registrant was closed, with interests aggregating $18,000,000 originally being sold to 710 subscribers of which $16,107,005 were sold to 644 subscribers as general partner interests and $1,892,995 were sold to 66 subscribers as limited partner interests.
The Registrant engages primarily in oil and gas development and production and is not involved in any other industry segment. See the selected financial data in Item 6 and the financial statements in Item 8 of this report for a summary of the Registrant’s revenue, income and identifiable assets.
The sale of crude oil and natural gas produced by the Registrant will be affected by a number of factors that are beyond the Registrant’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 Registrant.
The market for crude oil is such that the Registrant anticipates it will be able to sell all the crude oil it can produce. Natural gas will be sold to local distribution companies, gas marketers and end users on the spot market. The spot market reflects immediate sales of natural gas without long-term contractual commitments. The future market condition for natural gas cannot be predicted with any certainty, and the Registrant may experience delays in marketing natural gas production and fluctuations in natural gas prices.
Many aspects of the Registrant’s activities are highly competitive including, but not limited to, the acquisition of suitable drilling prospects and the procurement of drilling and related oil field equipment, and are subject to governmental regulation, both at Federal and state levels. The Registrant’s ability to compete depends on its financial resources and on the managing general partner’s staff and facilities, none of which are significant in comparison with those of the oil and gas exploration, development and production industry as a whole. Federal and state regulation of oil and gas operations generally includes drilling and spacing of wells on producing acreage, the imposition of maximum allowable production rates, the taxation of income and other items, and the protection of the environment.
The Registrant does not have any employees of its own. MD is responsible for all management functions. Mewbourne Oil Company (“MOC”), a wholly owned subsidiary of Mewbourne Holdings, Inc., which is also the parent of the Registrant’s managing general partner, has been appointed Program Manager and is responsible for activities in accordance with a Drilling Program Agreement entered into by the Registrant, MD and MOC. At March 31, 2008, MOC employed 183 persons, many of whom dedicated a part of their time to the conduct of the Registrant’s business during the period for which this report is filed.
The production of oil and gas is not considered subject to seasonal factors although the price received by the Registrant for natural gas sales will generally tend to increase during the winter months. Order backlog is not pertinent to the Registrant’s business.
ITEM 1A.
ITEM 1A. Risk Factors
Oil and natural gas prices are volatile. A decline in prices could adversely affect the Registrant’s financial position, financial results, and cash flows.
Revenues, operating results, and profitability depend primarily upon the prices received for oil and natural gas sales. Prices also affect the amount of cash flow available for distribution. In addition, cost ceiling write-downs may be necessary in the future if prices fall significantly.
Historically, the markets for oil and natural gas have been volatile and they are likely to continue to be volatile. Wide fluctuations in oil and natural gas prices may result from relatively minor changes in the supply of and demand for oil and natural gas, market uncertainty and other factors that are beyond the Registrant’s control, including:
•
worldwide and domestic supplies of oil and natural gas;
•
weather conditions;
•
the level of consumer demand;
•
the price and availability of alternative fuels;
•
the proximity and capacity of natural gas pipelines and other transportation facilities;
•
the price and level of foreign imports;
•
domestic and foreign governmental regulations and taxes;
•
the ability of the members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and production controls;
•
political instability or armed conflict in oil-producing regions; and
•
overall domestic and global economic conditions.
These factors and the volatility of the energy markets make it extremely difficult to predict future oil and natural gas price movements with any certainty. Declines in oil and natural gas prices would not only reduce revenue, but could reduce the amount of oil and natural gas that can be produced economically and, as a result, could have a material adverse effect on the Registrant’s financial condition, results of operations and reserves. Further, oil and natural gas prices do not necessarily move in tandem. Because approximately 81% of the Registrant’s reserves at December 31, 2007 were natural gas reserves, the Registrant is more affected by movements in natural gas prices.
The actual quantities and present value of proved reserves may prove to be lower than estimated.
This report contains estimates of proved reserves. These estimates are based upon various assumptions, including assumptions required by the SEC relating to oil and natural gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. The process of estimating oil and natural gas reserves is complex. The process involves significant decisions and assumptions in the evaluation of available geological, geophysical, engineering and economic data for each reservoir. Therefore, these estimates are inherently imprecise.
Actual future production, oil and natural gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and natural gas reserves most likely will vary from these estimates. Such variations may be significant and could materially affect the estimated quantities and present value of proved reserves. In addition, the Registrant may adjust estimates of proved reserves to reflect production history, results of exploration and development drilling, prevailing oil and natural gas prices and other factors, many of which are beyond the Registrant’s control. The Registrant’s properties may also be susceptible to hydrocarbon drainage from production by operators on adjacent properties.
Future price declines may result in a write-down of asset carrying values.
The Registrant utilizes the full-cost method of accounting for costs related to oil and natural gas properties. Under this method, all such costs (for both productive and nonproductive properties) are capitalized and amortized on an aggregate basis over the estimated lives of the properties using the unit-of-production method. However, these capitalized costs are subject to a ceiling test which limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved oil and natural gas reserves discounted at 10% plus the lower of cost or market value of unproved properties. The full-cost ceiling is evaluated at the end of each quarter using the prices for oil and natural gas at that date. A significant decline in oil and natural gas prices from current levels, or other factors, without other mitigating circumstances, could cause a future write-down of capitalized costs and a non-cash charge against future earnings.
The Registrant’s ceiling test calculations for the year ended December 31, 2007 indicated no impairment of oil and natural gas properties.
Oil and natural gas drilling and producing operations can be hazardous and may expose the Registrant to environmental liabilities.
Oil and natural gas operations are subject to many risks, including well blowouts, cratering and explosions, pipe failure, fires, formations with abnormal pressures, uncontrollable flows of oil, natural gas, brine or well fluids, and other environmental hazards and risks. If any of these risks occurs, the Registrant could sustain substantial losses as a result of:
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injury or loss of life;
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severe damage to or destruction of property, natural resources and equipment;
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pollution or other environmental damage;
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clean-up responsibilities;
•
regulatory investigations and administrative, civil and criminal penalties; and
•
injunctions resulting in limitation or suspension of operations.
There is inherent risk of incurring significant environmental costs and liabilities in exploration and production operations due to generation, handling, and disposal of materials, including wastes and petroleum hydrocarbons. The Registrant may incur joint and several, strict liability under applicable U.S. federal and state environmental laws in connection with releases of petroleum hydrocarbons and wastes on, under or from leased or owned properties, some of which have been used for oil and natural gas exploration and production activities for a number of years, often by third parties not under the Registrant’s control. While the Registrant maintains insurance against some, but not all, of the risks described above, the Registrant’s insurance may not be adequate to cover casualty losses or liabilities. Also, in the future the Registrant may not be able to obtain insurance at premium levels that justify its purchase.
In addition, in response to studies suggesting that emissions of certain gases may be contributing to warming of the earth’s atmosphere, many states are beginning to consider initiatives to track and record these gases, generally referred to as “greenhouse gases,” with several states having already adopted regulatory initiatives aimed at reducing emissions of greenhouse gases. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are included among the types of gases targeted by greenhouse gas initiatives and laws. This movement is in its infancy but regulatory initiatives or legislation placing restrictions on emissions of methane or carbon dioxide that may be imposed in various states of the United States could adversely affect operations and the demand for oil and gas products.
ITEM 1B.
ITEM 1B. Unresolved Staff Comments
None.
ITEM 2.
ITEM 2. Properties
The Registrant’s properties consist primarily of interests in properties on which oil and gas wells are located. Such property interests are often subject to landowner royalties, overriding royalties and other oil and gas leasehold interests.
Fractional working interests in developmental oil and gas prospects located primarily in the Anadarko Basin of Western Oklahoma, the Texas Panhandle, and the Permian Basin of New Mexico and West Texas, were acquired by the Registrant, resulting in the Registrant’s participation in the drilling of oil and gas wells. At December 31, 2007, 65 wells had been drilled and were productive and 9 wells had been drilled and abandoned. The Registrant had no drilling activity for the years ended December 31, 2007 and 2006.
Reserve estimates were prepared by Forrest A Garb & Associates, Inc., the Registrant’s independent petroleum consultants, in accordance with guidelines established by the Securities and Exchange Commission.
ITEM 3.
ITEM 3. Legal Proceedings
The Registrant is not aware of any pending legal proceedings to which it is a party.
ITEM 4.
ITEM 4. Submission of Matters to a Vote of Security Holders
No matter was submitted to a vote of security holders during the period ended December 31, 2007 covered by this report.
PART II
ITEM 5.
ITEM 5. Market for Registrant’s Common Equity and Related Stockholder Matters
At March 31, 2008, the Registrant had 18,000 outstanding limited and general partnership interests held of record by 710 subscribers. There is no established public or organized trading market for the limited and general partner interests.
Revenues which, in the sole judgment of the managing general partner, are not required to meet the Registrant’s obligations will be distributed to the partners at least quarterly in accordance with the Registrant’s Partnership Agreement. Distributions made to limited and general partners during the years ended December 31, 2007 and 2006 were $2,140,027 and $3,705,705, respectively.
ITEM 6.
ITEM 6. Selected Financial Data
The following table sets forth selected financial data for the years ended December 31, 2007 and 2006:
ITEM 7.
ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
General
The Registrant was organized as a Delaware limited partnership on February 19, 2003. The offering of limited and general partnership interests began May 16, 2003 as a part of an offering registered under the name Mewbourne Energy Partners 02-03 Drilling Programs. The offering of limited and general partner interests in the Registrant concluded July 9, 2003, with total investor partner contributions of $18,000,000.
The Registrant was formed to engage primarily in the business of drilling development wells, to produce and market crude oil and natural gas produced from such properties, to distribute any net proceeds from operations to the general and limited partners and to the extent necessary, acquire leases which contain drilling prospects. The economic life of the Registrant depends on the period over which the Registrant’s oil and gas reserves are economically recoverable.
Results of Operations
The following table sets forth certain operating data for the years ended December 31, 2007 and 2006:
Year ended December 31, 2007 compared to the year ended December 31, 2006
Oil and natural gas sales. As shown in the table above, total oil and gas sales decreased $1,098,562 (27%) for the year ended December 31, 2007 as compared to the year ended December 31, 2006. Of this decrease, $148,481 and $1,074,676, respectively, were related to decreases in volumes of oil and gas sold. Volumes of oil and gas sold decreased 2,180 bbls of oil and 167,819 mcf of gas for the year ended December 31, 2007 as compared to the year ended December 31, 2006. The decrease in volumes of oil and gas sold was primarily due to normal declines in production and are not expected to return to previous levels of production. These decreases were partially offset by increases of $26,356 and $98,239 related to increases in the average price of oil and gas sold. The average oil price increased to $68.09 per bbl for the year ended December 31, 2007 from $63.81 per bbl for the year ended December 31, 2006. The average gas price increased to $6.40 per mcf for the year ended December 31, 2007 from $6.23 per mcf for the year ended December 31, 2006.
Lease operating expense and production taxes. Lease operating expense decreased from $494,639 in 2006 to $451,380 in 2007. Lease operating expense decreased due to fewer well repairs in 2007. Production taxes decreased from $307,106 in 2006 to $232,760 in 2007. Production taxes decreased due to decreased oil and gas revenues for 2007.
Interest income. Interest income decreased from $3,225 in 2006 to $1,438 in 2007 due to expenditures for the drilling of oil and gas wells, which resulted in a decrease of capital available for investments.
Depreciation, depletion and amortization. Depreciation, depletion and amortization decreased from $1,208,828 in 2006 to $597,753 in 2007 due to reductions in the full cost pool amortizable base. The lower amortizable base was caused by quarterly cost ceiling write-downs in 2006.
Cost ceiling write-down. There was a cost ceiling write-down of $6,268,874 in 2006. The cost ceiling write-down was caused by lower gas prices during the year. There was no cost ceiling write-down in 2007.
Liquidity and capital resources
Cash increased by $10,335 during the year ended December 31, 2007. Cash flows from operating activities were utilized primarily for cash distributions to partners. All wells for which funds have been committed have been drilled. Any incidental future capital expenditures incurred will be paid with revenues generated through oil and gas sales. Revenues which, in the sole judgment of the managing general partner, are not required to meet the Registrant’s obligations will be distributed to the partners at least quarterly in accordance with the Registrant’s Partnership Agreement.
Critical Accounting Policies
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Significant estimates inherent in the Registrant’s financial statements include the estimate of oil and gas reserves and future abandonment costs. Changes in oil and gas prices and the changes in production estimates could have a significant effect on reserve estimates. The reserve estimates directly impact the computation of depreciation, depletion, and amortization, asset retirement obligation, and the ceiling test for the Registrant’s oil and gas properties.
The Registrant 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. Oil and gas properties 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. The present value of future net cash flows has been prepared assuming year-end selling prices, year-end development and production costs and a 10 percent annual discount rate.
All financing activities of the Registrant are reported in the financial statements. The Registrant does not engage in any off-balance sheet financing arrangements. Additionally, the Registrant has no contractual obligations but has a financial obligation to plug and abandon non-producing properties as discussed below.
Asset Retirement Obligations
In accordance with Statement of Financial Accounting Standard No. 143 (“FAS 143”), “Accounting for Asset Retirement Obligations”, the Partnership has recognized an estimated liability for future plugging and abandonment costs. This statement affects the financial accounting and reporting obligations associated with the retirement and disposal of long-lived assets, including the Partnership’s oil and gas properties, and the associated asset retirement 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 years ended December 31, 2007 and 2006, is as follows:
Organization and Related Party Transactions
The Partnership was organized on February 19, 2003 in accordance with the laws of the state of Delaware. MD, a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no equity interest in the Registrant. 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 well 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. Reimbursement to MOC for operator charges totaled $246,669 and $251,516 for the years ended December 31, 2007 and 2006, respectively. Operator charges are billed in accordance with the program and partnership agreements.
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. Under this arrangement, $111,901 and $151,110 were allocated to the Partnership during the years ended December 31, 2007 and 2006, respectively.
The Partnership participates in oil and gas activities through a Drilling Program Agreement (the “Program”). The Partnership and MD are parties to the Program Agreement. The costs and revenues of the Program are allocated to MD and the Partnership as follows:
(1) As noted above, 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 7A.
ITEM 7A. Quantitative and Qualitative Disclosures about Market Risk
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.
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 year ended December 31, 2007, a 10% change in the price received for natural gas production would have had an approximate $269,000 impact on revenue.
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 8.
ITEM 8. Financial Statements and Supplementary Data
The required financial statements of the Registrant are contained in a separate section of this report following the signature attestation. See “Item 15. Exhibits, Financial Statement Schedules and Reports on Form 8-K”.
ITEM 9.
ITEM 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.
ITEM 9A.
ITEM 9A. Controls and Procedures
(a) Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this report, MD’s management conducted an evaluation, under the supervision and with the participation of MD’s principal executive officer and principal financial officer, of the Registrant’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act). Based on this evaluation, MD's principal executive officer and principal financial officer concluded that, as of the end of the period covered by this report, the Registrant’s disclosure controls and procedures are effective. Notwithstanding the foregoing, a control system, no matter how well designed and operated, can provide only reasonable, not absolute, assurance that it will detect or uncover failures within the Registrant to disclose material information otherwise required to be set forth in the Registrant’s periodic reports.
(b) MD Management’s Annual Report on Internal Control Over Financial Reporting
MD’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rules 13a-15(f). Under the supervision and with the participation of MD’s management, including MD’s principal executive officer and principal financial officer, MD conducted an evaluation of the effectiveness of the Partnership’s internal control over financial reporting based on the framework in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on MD’s evaluation under the framework in Internal Control - Integrated Framework, MD’s management concluded that internal control over financial reporting was effective as of December 31, 2007. This annual report does not include an attestation report of the Registrant’s registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by the Registrant’s registered public accounting firm pursuant to temporary rules of the Securities and Exchange Commission that permit the Registrant to provide only management’s report in this annual report. There have been no changes in MD’s internal controls for the quarter ended December 31, 2007 or in other factors which have materially affected, or are reasonably likely to materially affect the internal controls over financial reporting.
PART III
ITEM 10.
ITEM 10. Directors and Executive Officers of the Registrant
The Registrant does not have any officers or directors. Under the Registrant’s Partnership Agreement, the Registrant’s managing partner, MD, is granted the exclusive right and full authority to manage, control and administer the Registrant’s business. MD is a wholly owned subsidiary of Mewbourne Holdings, Inc.
Set forth below are the names, ages and positions of the directors and executive officers of MD, the Registrant’s managing general partner. Directors of MD are elected to serve until the next annual meeting of stockholders or until their successors are elected and qualified.
Curtis W. Mewbourne, age 72, formed Mewbourne Holdings, Inc. in 1965 and serves as Chairman of the Board and President of Mewbourne Holdings, Inc., MD and MOC. He has operated as an independent oil and gas producer for the past 42 years. Mr. Mewbourne received a Bachelor of Science Degree in Petroleum Engineering from the University of Oklahoma in 1957. Mr. Mewbourne is the father of Dorothy M. Cuenod, Ruth M. Buckley, and Julie M. Greene and the father-in-law of J. Roe Buckley.
J. Roe Buckley, age 45, joined Mewbourne Holdings, Inc. in July, 1990 and serves as Vice President and Chief Financial Officer of both MD and MOC. Mr. Buckley was employed by Mbank Dallas from 1985 to 1990 where he served as a commercial loan officer. He received a Bachelor of Arts in Economics from Sewanee in 1984. Mr. Buckley is the son-in-law of Curtis W. Mewbourne and is married to Ruth M. Buckley. He is also the brother-in-law of Dorothy M. Cuenod and Julie M. Greene.
Alan Clark, age 55, joined MOC in 1979 and serves as Treasurer and Controller of both MD and MOC. Prior to joining MOC, Mr. Clark was employed by Texas Oil and Gas Corporation as Assistant Supervisor of joint interest accounting from 1976 to 1979. Mr. Clark has served in several accounting/finance positions with MOC prior to his current assignment. Mr. Clark received a Bachelor of Business Administration from the University of Texas at Arlington.
Michael F. Shepard, age 61, joined MOC in 1986 and serves as Secretary and General Counsel of MD. He has practiced law exclusively in the oil and gas industry since 1979 and formerly was counsel with Parker Drilling Company and its Perry Gas subsidiary for seven years. Mr. Shepard holds the Juris Doctor degree from the University of Tulsa where he received the National Energy Law and Policy Institute award as the outstanding graduate in the Energy Law curriculum. He received a B.A. degree, magna cum laude, from the University of Massachusetts in 1976. Mr. Shepard is a member of the bar in Texas and Oklahoma.
Dorothy M. Cuenod, age 47 received a B.A. degree in Art History from The University of Texas and a Masters of Business Administration Degree from Southern Methodist University. Since 1984 she has served as a Director and Assistant Secretary of both MD and MOC. Ms. Cuenod is the daughter of Curtis W. Mewbourne and is the sister of Ruth M. Buckley and Julie M. Greene. She is also the sister-in-law of J. Roe Buckley.
Ruth M. Buckley, age 46, received a Bachelor of Science Degree in both Engineering and Geology from Vanderbilt University. Since 1987 she has served as a Director and Assistant Secretary of both MD and MOC. Ms. Buckley is the daughter of Curtis W. Mewbourne and is the sister of Dorothy M. Cuenod and Julie M. Greene. She is also the wife of J. Roe Buckley.
Julie M. Greene, age 44, received a B.A. degree in Business Administration from The University of Oklahoma. Since 1988 she has served as a Director and Assistant Secretary of both MD and MOC. Prior to that time she was employed by Rauscher, Pierce, Refsnes, Inc. Ms. Greene is the daughter of Curtis W. Mewbourne and is the sister of Dorothy M. Cuenod and Ruth M. Buckley. She is also the sister-in-law of J. Roe Buckley.
The organizational structure of the Partnership does not provide for an audit committee and therefore the Partnership does not have an audit committee or financial expert serving in such capacity.
ITEM 11.
ITEM 11. Executive Compensation
The Registrant does not have any officers or directors. Management of the Registrant is vested in the managing general partner. None of the officers or directors of MD or MOC will receive remuneration directly from the Registrant, but will continue to be compensated by their present employers. The Registrant will reimburse MD and MOC and affiliates thereof for certain costs of overhead falling within the definition of Administrative Costs, including without limitation, salaries of the officers and employees of MD and MOC; provided that no portion of the salaries of the directors or of the executive officer of MOC or MD may be reimbursed as Administrative Costs.
ITEM 12.
ITEM 12. Security Ownership of Certain Beneficial Owners and Management
(a) Beneficial owners of more than five percent
(b) Security ownership of management
The Registrant does not have any officers or directors. The managing general partner of the Registrant, MD, has the exclusive right and full authority to manage, control and administer the Registrant’s business. Under the Registrant’s Partnership Agreement, limited and general partners holding a majority of the outstanding limited and general partnership interests have the right to take certain actions, including the removal of the managing general partner. The Registrant is not aware of any current arrangement or activity that may lead to such removal.
ITEM 13.
ITEM 13. Certain Relationships and Related Transactions
Transactions with MD and its affiliates
Pursuant to the Registrant’s Partnership Agreement, the Registrant had the following related party transactions with MD and its affiliates during the years ended December 31, 2007 and 2006:
The Registrant participates in oil and gas activities through a drilling program created by the Program. Pursuant to the Program, MD pays approximately 30% of the Program’s capital expenditures and approximately 40% of its operating and general and administrative expenses. The Registrant pays the remainder of the costs and expenses of the Program. In return, MD is allocated approximately 40% of the Program’s revenues.
ITEM 14.
ITEM 14. Principal Accountant Fees and Services
In August 2006, the Registrant changed audit firms from PricewaterhouseCoopers LLP to BDO Seidman, LLP. The aggregate fees billed, including expenses, by BDO Seidman, LLP for 2007 and 2006 for services are set forth below:
PART IV
ITEM 15.
ITEM 15. Exhibits, Financial Statements, Financial Statement Schedules and Reports on Form 8-K
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereto duly authorized.
Mewbourne Energy Partners 03-A, L.P.
By:
Mewbourne Development Corporation
Managing General Partner
By:
/s/ Curtis W. Mewbourne
Curtis W. Mewbourne
President and Director
(Principal Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the date indicated.
Supplemental Information to be Furnished With Reports Filed Pursuant to Section 15(d) of the Act by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Act
No annual report or proxy material has been sent to the Registrant’s security holders.
MEWBOURNE ENERGY PARTNERS 03-A, L.P.
FINANCIAL STATEMENTS
WITH REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
For the years ended December 31, 2007 and 2006
Report of Independent Registered Public Accounting Firm
To the Partners of Mewbourne Energy Partners 03-A, L.P. and to the Board of Directors of Mewbourne Development Corporation Tyler, Texas
We have audited the accompanying balance sheets of Mewbourne Energy Partners 03-A, L.P. as of December 31, 2007 and 2006 and the related statements of operations, changes in partners’ capital, and cash flows for each of the two years in the period ended December 31, 2007. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audits included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Mewbourne Energy Partners 03-A, L.P. at December 31, 2007 and 2006, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2007, in conformity with accounting principles generally accepted in the United States of America.
/s/ BDO Seidman, LLP
Dallas, Texas
March 31, 2008
MEWBOURNE ENERGY PARTNERS 03-A, LP
BALANCE SHEETS
December 31, 2007 and 2006
The accompanying notes are an integral part of the financial statements.
MEWBOURNE ENERGY PARTNERS 03-A, LP
STATEMENTS OF OPERATIONS
For the years ended December 31, 2007 and 2006
MEWBOURNE ENERGY PARTNERS 03-A, LP
STATEMENTS OF CHANGES IN PARTNERS’ CAPITAL
For the years ended December 31, 2007 and 2006
The accompanying notes are an integral part of the financial statements.
MEWBOURNE ENERGY PARTNERS 03-A, LP
STATEMENTS OF CASH FLOWS
For the years ended December 31, 2007 and 2006
The accompanying notes are an integral part of the financial statements.
Mewbourne Energy Partners 03-A, L.P.
NOTES TO FINANCIAL STATEMENTS
1. Significant Accounting Policies:
Accounting for Oil and Gas Producing Activities
Mewbourne Energy Partners 03-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 19, 2003. The offering of limited and general partnership interests began May 16, 2003 as a part of an offering registered under the name Mewbourne Energy Partners 02-03 Drilling Programs, (the “Program”), and concluded July 9, 2003, with total investor contributions of $18,000,000 originally being sold to 710 subscribers of which $16,107,005 were sold to 644 subscribers as general partner equity interests and $1,892,995 were sold to 66 subscribers as limited partner equity interests. During 2005 all general partner equity interests were converted to limited partner interests. The managing general partner has no equity interest in the Partnership.
The Program’s sole business is the development and production of oil and gas with a concentration on gas. A substantial portion of the Program’s gas production is being sold regionally in the spot market. Due to the highly competitive nature of the spot market, prices are subject to seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon obtaining transportation services provided by pipelines. The prices received for the Program’s oil and gas are subject to influences such as global consumption and supply trends.
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 December 31, 2007 and 2006, 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 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 year ended December 31, 2007. There were quarterly cost ceiling write-downs totaling $6,268,874 for the year ended December 31, 2006.
Significant estimates inherent in the Registrant’s financial statements include the estimate of oil and gas reserves and future abandonment costs. Changes in oil and gas prices and the changes in production estimates could have a significant effect on reserve estimates. The reserve estimates directly impact the computation of depreciation, depletion, and amortization, asset retirement obligation, and the ceiling test for the Registrant’s oil and gas properties.
The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash
The Partnership considers all highly liquid investments, those with original maturities of three months or less at the date of acquisition, to be cash equivalents. The Partnership maintains all its cash in one financial institution. At various times throughout the year, the cash amount may be in excess of the amount insured by the Federal Deposit Insurance Corporation.
Asset Retirement Obligations
In accordance with FAS 143, 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 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 years ended December 31, 2007 and 2006, is as follows:
Oil and Gas Sales
The Program’s oil and condensate production is sold and revenue recognized at or near the Program’s wells under short-term purchase contracts at prevailing prices in accordance with arrangements which are customary in the oil industry. Sales of gas applicable to the Program’s interest are recorded as revenue when the gas is metered and title transferred pursuant to the gas sales contracts covering the Program’s interest in gas reserves. The Partnership uses the sales method to recognize oil and gas revenue whereby revenue is recognized for the amount of production taken regardless of the amount for which the Partnership is entitled based on its working interest ownership. As of December 31, 2007 and 2006, no material gas imbalances between the Partnership and other working interest owners existed.
Income Taxes
The Partnership is treated as a partnership for income tax purposes, and as a result, income of the Partnership is reported on the tax returns of the partners and no recognition is given to income taxes in the financial statements. The Partnership’s financial reporting bases of its net assets exceeded the tax bases of its net assets by $5,846,415 and $5,633,279 at December 31, 2007 and 2006, respectively.
2. Organization and Related Party Transactions:
The Partnership was organized on February 19, 2003 in accordance with the laws of the state of Delaware. MD, a Delaware Corporation, has been appointed as the Registrant’s managing general partner. MD has no equity interest in the Registrant. 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 well owners of the well on which the costs were incurred. The partnership will be charged 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. Reimbursement to MOC for operator charges totaled $246,669 and $251,516 for the years ended December 31, 2007 and 2006, respectively. Operator charges are billed in accordance with the program and partnership agreements.
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. Under this arrangement, $111,902 and 151,110 were allocated to the Partnership during the years ended December 31, 2007 and 2006, respectively.
The Partnership participates in oil and gas activities through a Drilling Program Agreement (the "Program"). The Partnership and MD are parties to the Program Agreement. The costs and revenues of the Program are allocated to MD and the Partnership as follows:
(1) As noted above, 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.
3. Quarterly Financial Data (unaudited):
Summarized unaudited quarterly financial data for 2007 and 2006 are as follows:
(a) Total revenue less operating costs.
(b) Includes cost ceiling write-down of $1,971,537.
(c) Includes cost ceiling write-down of $705,339.
(d) Includes cost ceiling write-down of $3,591,998.
4. Supplemental Oil and Gas Information (unaudited):
The tables presented below provide supplemental information about oil and natural gas exploration and production activities as defined by SFAS No. 69, “Disclosures about Oil and Gas Producing Activities”.
Costs Incurred and Capitalized Costs:
Costs incurred in oil and natural gas acquisition, exploration and development activities for the years ended December 31, 2007 and 2006:
Capitalized costs related to oil and natural gas acquisition, exploration and development activities for the years ended December 31, 2007 and 2006 are as follows:
Estimated Net Quantities of Proved Oil and Gas Reserves:
Reserve estimates as well as certain information regarding future production and discounted cash flows were determined by the Partnership’s independent petroleum consultants and MOC’s petroleum reservoir engineers. The Partnership considers reserve estimates to be reasonable, however, due to inherent uncertainties and the limited nature of reservoir data, estimates of oil and gas reserves are imprecise and subject to change over time as additional information becomes available.
There have been no favorable or adverse events that have caused a significant change in estimated proved reserves since December 31, 2007 The Partnership has no long-term supply agreements or contracts with governments or authorities in which it acts as producer nor does it have any interest in oil and gas operations accounted for by the equity method. All reserves are located onshore within the United States.
Proved Reserves:
(1) All of these reserves are categorized as proved developed as of December 31, 2007 and 2006.
MEWBOURNE ENERGY PARTNERS 03-A, L.P.
INDEX TO EXHIBITS
The following documents are incorporated by reference in response to Item 15(a)3.