MEWBOURNE ENERGY PARTNERS 00-A LP - 10-Q Quarterly Report

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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, 2003

or

[ ] TRANSITION REPORT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the transition period from ____________ to ____________

Commission File No. 333-76911

MEWBOURNE ENERGY PARTNERS 00-A, L.P.

Delaware 75-2866283
- ---------------------------------------- ----------------------
(State or jurisdiction of (I.R.S. Employer
incorporation or organization) 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 or 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. [X] Yes [ ] No

MEWBOURNE ENERGY PARTNERS 00-A, L. P.

INDEX

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MEWBOURNE ENERGY PARTNERS 00-A, L. P.

Part I - Financial Information

Item 1. Financial Statements

BALANCE SHEETS
June 30, 2003 and December 31, 2002

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

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MEWBOURNE ENERGY PARTNERS 00-A, L. P.

STATEMENTS OF INCOME
For the three months ended June 30, 2003 and 2002, and
the six months ended June 30, 2003 and 2002
(Unaudited)

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

4

MEWBOURNE ENERGY PARTNERS 00-A, L. P.

STATEMENTS OF CASH FLOWS
For the six months ended June 30, 2003 and 2002
(Unaudited)

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

5

MEWBOURNE ENERGY PARTNERS 00-A, L. P.

STATEMENT OF CHANGES IN PARTNERS' CAPITAL
For the six months ended June 30, 2003
(Unaudited)

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

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MEWBOURNE ENERGY PARTNERS 00-A, L.P.

NOTES TO FINANCIAL STATEMENTS
(Unaudited)

1. Accounting Policies

Reference is hereby made to the Partnership's Annual Report on Form 10-K for
2002, 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.

2. Accounting for Oil and Gas Producing Activities

Mewbourne Energy Partners 00-A, L.P., (the "Partnership"), a Delaware limited
partnership formed on February 15, 2000, is engaged primarily in oil and gas
development and production in Texas, Oklahoma, New Mexico, and Kansas. The
offering of limited and general partnership interests began May 5, 2000 as a
part of an offering registered under the name Mewbourne Energy Partners 99-00
Drilling Programs and concluded October 31, 2000, with total investor
contributions of $10,000,000.

The Partnership follows the full-cost method of accounting for its oil and gas
activities. Under the full-cost method, all productive and nonproductive 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, 2003 and June 30, 2002 substantially all capitalized costs were subject
to amortization. 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 periodic 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.

3. Comprehensive Income

Total comprehensive income (loss) equals net income (loss) during each of the
periods presented herein.

4. Asset Retirement Obligations

On January 1, 2003, the Partnership adopted Statement of Financial Accounting
Standard No. 143 ("FAS 143"), "Accounting for Asset Retirement Obligations."
This statement changes 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

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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 of 4.25%. 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.

Upon adoption of FAS 143 on January 1, 2003, the Partnership recorded a
discounted liability of $174,713, increased the net full cost pool by $216,505
and recognized a one-time cumulative effect adjustment of $(41,791). The
increase in the net full cost pool included $148,744 for the reversal of
accumulated depreciation related to the inclusion of estimated salvage value of
equipment on the Partnership's oil and gas properties. Prior to the adoption of
FAS 143, the Partnership assumed salvage value approximated plugging and
abandonment costs and as a result was not included in the full cost pool.

A reconciliation of the Partnership's liability for well plugging and
abandonment costs for the six months ended June 30, 2003, is as follows:

Balance upon adoption at January 1, 2003 $174,713
Accretion expense 3,712
--------

Balance at June 30, 2003 $178,425
--------

5. Recently Issued Accounting Standards

In June 2002, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 146 (FAS 146), Accounting for Costs
Associated with Exit or Disposal Activities. This statement addresses financial
accounting and reporting for costs associated with exit or disposal activities
and was effective for the Partnership beginning January 1, 2003. The adoption of
FAS 146 did not have a material impact on the Partnership.

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Item 2 Management's Discussion and Analysis of Financial Condition and
Results of Operations

Liquidity and Capital Resources

Mewbourne Energy Partners 00-A, L.P. (the "Partnership")was formed February 15,
2000. The offering of limited and general partnership interests began on May 5,
2000 and concluded on October 31, 2000, with investor partner contributions of
$10,000,000.

The Partnership has acquired interests in oil and gas prospects for the purpose
of development drilling. The Partnership participated in the drilling of 32
wells. 30 wells were productive and 2 wells were abandoned. Of the 30 productive
wells, 27 were producing and 3 were plugged and abandoned at June 30, 2003.

Operations will be conducted with available funds and revenues generated from
oil and gas activities. No bank borrowing is anticipated. The Partnership had
net working capital at June 30, 2003 of $471,690.

During the six months ended June 30, 2003, the Partnership made cash
distributions to the investor partners in the amount of $1,074,690 as compared
to $795,995 for the six months ended June 30, 2002. The Partnership expects that
cash distributions will continue during 2003 as additional oil and gas revenues
are received.

The sale of crude oil and natural gas produced by the Partnership will be
affected by a number of factors which 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

Three months ended June 30, 2003 as compared to the three months ended June 30,
2002.

Oil and gas revenues. Oil and gas revenues during the three months ended June
30, 2003 totaled $664,510. Production volumes during the period were
approximately 5,726 bbls of oil and 95,839 mcf of gas at corresponding average
realized prices of $27.81 per bbl of oil and $5.27 per mcf of gas. Oil and gas
revenues during the three months ended June 30, 2002 totaled $545,929.
Production volumes during the period were approximately 732 bbls of oil and
164,891 mcf of gas at corresponding average realized prices of $25.86 per bbl of
oil and $3.20 per mcf of gas. Oil and gas revenues increased primarily due to
the increase in oil production volumes and increased oil and gas prices. The
increased oil production volumes were attributable to the addition of 2 New
Mexico wells.

Interest Income. Interest income was $255 during the three month period ended
June 30, 2003 as compared to $1,306 during the three months ended June 30, 2002.
The decrease is primarily due to the decrease in capital available for
investment.

Lease operations and production taxes. Lease operating expense during the period
ended June 30, 2003 totaled $61,895 compared to $123,504 for the period ended
June 30, 2002. Production taxes during the period ended June 30, 2003 totaled
$51,573 compared to $41,616 for the period ended June 30, 2002. Lease operating
expense decreased primarily due to the workover operations on two wells in 2002
compared to no workover operations in 2003. Production taxes increased due to
increased oil and gas revenues in 2003.

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Depreciation, depletion, and amortization. Depreciation, depletion, and
amortization of $156,800 for the three month period ended June 30, 2003 was
comparative to depreciation, depletion, and amortization of $180,360 for the
three month period ended June 30, 2002.

Administrative and general expense. Administrative and general expense for the
three month period ended June 30, 2003 totaled $40,592 compared to $16,114 for
the period ended June 30, 2002. The increase is primarily due to the increase in
oil and gas revenues.

Six months ended June 30, 2003 as compared to the six months ended June 30,
2002.

Oil and gas revenues. Oil and gas revenues during the six months ended June 30,
2003 totaled $1,573,306. Production volumes during the period were approximately
13,353 bbls of oil and 196,730 mcf of gas at corresponding average realized
prices of $31.24 per bbl of oil and $5.88 per mcf of gas. Oil and gas revenues
during the six months ended June 30, 2002 totaled $879,852. Production volumes
during the period were approximately 1,693 bbls of oil and 319,088 mcf of gas at
corresponding average realized prices of $21.37 per bbl of oil and $2.64 per mcf
of gas. Oil and gas revenues increased primarily due to the increase in oil
production volumes and increased oil and gas prices. The increased oil
production volumes were attributable to the addition of 2 New Mexico wells.

Interest Income. Interest income was $395 during the six month period ended June
30, 2003 as compared to $3,514 during the six months ended June 30, 2002. The
decrease is primarily due to the decrease in capital available for investment.

Lease operations and production taxes. Lease operating expense during the period
ended June 30, 2003 totaled $123,930 compared to $224,004 for the period ended
June 30, 2002. Production taxes during the period ended June 30, 2003 totaled
$125,768 compared to $66,117 for the period ended June 30, 2002. Lease operating
expense decreased primarily due to the workover operations on two wells in 2002
compared to no workover operations in 2003. Production taxes increased due to
increased oil and gas revenues in 2003.

Depreciation, depletion, and amortization. Depreciation, depletion, and
amortization of $311,612 for the six month period ended June 30, 2003 was
comparative to depreciation, depletion, and amortization of $343,812 for the six
month period ended June 30, 2002.

Administrative and general expense. Administrative and general expense for the
six month period ended June 30, 2003 totaled $69,892 compared to $39,736 for the
period ended June 30, 2002. The increase is primarily due to the increase in oil
and gas revenues.

Asset Retirement Obligation

In accordance with FAS 143, the Partnership has recognized an estimated
liability for future oil and gas well plugging and abandonment costs (see Note
4). The estimated liability is based on historical experience and estimated well
lives. The liability is discounted using the credit-adjusted risk-free rate of
4.25%. 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.

Upon adoption of FAS 143 on January 1, 2003, the Partnership recorded a
discounted liability of $174,713, increased the net full cost pool by $216,505
and recognized a one-time cumulative effect adjustment of $(41,791). The
increase in the net full cost pool included $148,744 for the reversal of
accumulated depreciation related to the inclusion of estimated salvage value of
equipment on the Partnership's oil and gas properties. Prior to the adoption of
FAS 143, the Partnership assumed salvage value approximated plugging and
abandonment costs and as a result was not included in the full cost pool.

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A reconciliation of the Partnership's liability for well plugging and
abandonment costs for the six months ended June 30, 2003, is as follows:

Balance upon adoption at January 1, 2003 $174,713
Accretion expense 3,712
--------

Balance at June 30, 2003 $178,425
--------

Recently Issued Accounting Standards

In June 2002, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 146 (FAS 146), Accounting for Costs
Associated with Exit or Disposal Activities. This statement addresses financial
accounting and reporting for costs associated with exit or disposal activities
and was effective for the Partnership beginning January 1, 2003. The adoption of
FAS 146 did not have a material impact on the Partnership.

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Item 4. Disclosure Controls and Procedures

Mewbourne Development Corporation ("MDC"), the Managing General Partner of the
Partnership, 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. Within 90 days prior to the filing of this
report, MDC's Chief Executive Officer and Chief Financial Officer have evaluated
the effectiveness of the design and operation of our disclosure controls and
procedures with the assistance and participation of other members of management.
Based upon that evaluation, MDC's Chief Executive Officer and Chief Financial
Officer concluded that our 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. There have been
no significant changes in MDC's internal controls or in other factors which
could significantly affect internal controls subsequent to the date MDC carried
out its evaluation.

Part II - Other Information

Item 1. Legal Proceedings
None.

Item 6. Exhibits and Reports on Form 8-K

(a) Exhibits

Exhibit
Number Description

31.1 Certification of Principal Executive Officer
Required by Rule 13a-14(a) of the Securities
Exchange Act of 1934, as amended.

31.2 Certification of Principal Financial Officer
Required by Rule 13a-14(a) of the Securities
Exchange Act of 1934, as amended.

32.1 Certification of Principal Executive Officer
Required by Rule 13a-14(b) of the Securities
Exchange Act of 1934, as amended, and 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002.

32.2 Certification of Principal Financial Officer
Required by Rule 13a-14(b) of the Securities
Exchange Act of 1934, as amended, and 18 U.S.C.
Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002.

(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 00-A, L.P.

By: Mewbourne Development Corporation
Managing General Partner

Date: August 13, 2003 By: /s/ Alan Clark
-------------------------------------
Alan Clark, Treasurer

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