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                                 FORM 10-Q


                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D. C.  20549

(Mark One)

(X)  QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
     EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2003

                                    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 number 0-17707

              Southwest Oil and Gas Income Fund VIII-A, L.P.
                  (Exact name of registrant as specified
                   in its limited partnership agreement)

Delaware                                          75-2220097
(State or other jurisdiction of                                  (I.R.S.
Employer
incorporation or organization)
          Identification No.)

                       407 N. Big Spring, Suite 300
                  _________Midland, Texas 79701_________
                 (Address of principal executive offices)

                      ________(432) 686-9927________
                      (Registrant's telephone number,
                           including area code)

Indicate  by  check  mark  whether 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:

                            Yes __X__ No _____

Indicate  by  check  mark whether registrant is an  accelerated  filer  (as
defined in Rule 12b-2 of the Exchange Act).

                             Yes ____ No __X__


         The total number of pages contained in this report is 26.

<PAGE>

Glossary of Oil and Gas Terms
The  following are abbreviations and definitions of terms commonly used  in
the  oil  and  gas industry that are used in this filing.  All  volumes  of
natural gas referred to herein are stated at the legal pressure base to the
state  or area where the reserves exit and at 60 degrees Fahrenheit and  in
most instances are rounded to the nearest major multiple.

     Bbl. One stock tank barrel, or 42 United States gallons liquid volume.

     Developmental well. A well drilled within the proved area of an oil or
natural gas reservoir to the depth of a stratigraphic horizon known  to  be
productive.

     Exploratory well. A well drilled to find and produce oil or gas in  an
unproved  area to find a new reservoir in a field previously  found  to  be
productive of oil or natural gas in another reservoir or to extend a  known
reservoir.

     Farm-out  arrangement. An agreement whereby the owner of the leasehold
or  working  interest  agrees to assign his interest  in  certain  specific
acreage  to  the assignee, retaining some interest, such as  an  overriding
royalty interest, subject to the drilling of one (1) or more wells or other
performance by the assignee.

     Field. An area consisting of a single reservoir or multiple reservoirs
all  grouped  on  or  related to the same individual geological  structural
feature and/or stratigraphic condition.

     Mcf. One thousand cubic feet.

     Oil. Crude oil, condensate and natural gas liquids.

     Overriding  royalty  interest. Interests that  are  carved  out  of  a
working  interest, and their duration is limited by the term of  the  lease
under which they are created.

<PAGE>
     Present  value  and  PV-10 Value. When used with respect  to  oil  and
natural gas reserves, the estimated future net revenue to be generated from
the  production of proved reserves, determined in all material respects  in
accordance  with  the  rules and regulations of the  SEC  (generally  using
prices  and costs in effect as of the date indicated) without giving effect
to  non-property  related  expenses  such  as  general  and  administrative
expenses,  debt service and future income tax expenses or to  depreciation,
depletion  and  amortization, discounted using an annual discount  rate  of
10%.

     Production  costs.  Costs incurred to operate and maintain  wells  and
related  equipment  and facilities, including depreciation  and  applicable
operating  costs  of support equipment and facilities and  other  costs  of
operating and maintaining those wells and related equipment and facilities.

     Proved Area. The part of a property to which proved reserves have been
specifically attributed.

     Proved  developed oil and gas reserves. Proved developed oil  and  gas
reserves  are  reserves that can be expected to be recovered from  existing
wells with existing equipment and operating methods.

     Proved properties. Properties with proved reserves.

     Proved  reserves. The estimated quantities of crude oil, natural  gas,
and  natural  gas liquids that geological and engineering data  demonstrate
with  reasonable  certainty to be recoverable in future  years  from  known
reservoirs under existing economic and operating conditions.

     Proved  undeveloped reserves. Proved undeveloped oil and gas  reserves
are  reserves that are expected to be recovered from new wells on undrilled
acreage,  or  from existing wells where a relatively major  expenditure  is
required for recompletion.

     Reservoir.  A porous and permeable underground formation containing  a
natural  accumulation  of  producible  oil  or  gas  that  is  confined  by
impermeable  rock  or water barriers and is individual  and  separate  from
other reservoirs.

     Royalty  interest.  An  interest in an oil and  natural  gas  property
entitling  the  owner to a share of oil or natural gas production  free  of
costs of production.

     Working  interest.  The operating interest that gives  the  owner  the
right  to  drill, produce and conduct operating activities on the  property
and a share of production.

     Workover.  Operations  on  a producing well  to  restore  or  increase
production.


<PAGE>

                      PART I. - FINANCIAL INFORMATION

Item 1.  Financial Statements

The  unaudited  condensed financial statements included  herein  have  been
prepared  by  the Registrant (herein also referred to as the "Partnership")
in  accordance  with generally accepted accounting principles  for  interim
financial information and with the instructions to Form 10-Q and Rule 10-01
of Regulation S-X.  Accordingly, they do not include all of the information
and  footnotes  required  by generally accepted accounting  principles  for
complete   financial  statements.   In  the  opinion  of  management,   all
adjustments necessary for a fair presentation have been included and are of
a  normal  recurring nature.  The financial statements should  be  read  in
conjunction with the audited financial statements and the notes thereto for
the  year  ended  December 31, 2002, which are found  in  the  Registrant's
Amendment No. 1 to its Annual Report on Form 10-K for 2002 filed  with  the
Securities and Exchange Commission on November 10, 2003.  The December  31,
2002  balance  sheet included herein has been derived from the Registrant's
Amendment  No.  1  to its Annual Report on Form 10-K for  2002.   Operating
results  for the three and nine month periods ended September 30, 2003  are
not necessarily indicative of the results for the full year.

Introductory Note - Statement of Financial Accounting Standard No. 143
The  Partnership implemented SFAS No. 143 effective January  1,  2003  (See
Note 3) to the Partnership's financial statements.

Introductory Note - Depletion Method
During  the fourth quarter of 2002, the Partnership changed its  method  of
providing  for depletion from the units-of-revenue method to the  units-of-
production  method  as  described in Notes 4 and  6  to  the  Partnership's
financial statements.

This  change  in depletion method was applied as a cumulative effect  of  a
change  in  accounting  principle effective as of  January  1,  2002.   The
unaudited condensed financial statements of the Partnership for the periods
ended September 30, 2002, included herein, have been restated (as described
in  Notes 4 and 6 to the Partnership's financial statements) using the  new
depletion   method  and  differ  from  those  previously  issued   in   the
Partnership's Quarterly Report on Form 10-Q for the periods ended September
30, 2002.


<PAGE>

              Southwest Oil and Gas Income Fund VIII-A, L.P.
                              Balance Sheets

                                 Septembe  December
                                  r 30,      31,
                                   2003      2002
                                  -----     -----
                                 (unaudit
                                   ed)
Assets
---------

Current assets:
 Cash and cash equivalents    $  169,914   56,709
  Receivable  from  Managing     121,416   133,263
General Partner
                                 --------  --------
                                 ----      ----
   Total current assets          291,330   189,972
                                 --------  --------
                                 ----      ----

Oil  and  gas  properties  -
using the full-
 cost method of accounting       5,344,49  5,438,77
                                 6         9
       Less      accumulated
depreciation,
         depletion       and     5,053,21  5,107,46
amortization                     8         6
                                 --------  --------
                                 ----      ----
      Net   oil   and    gas     291,278   331,313
properties
                                 --------  --------
                                 ----      ----
                              $  582,608   521,285
                                 =======   =======

Liabilities  and   Partners'
Equity
----------------------------
------------

Current     liability      -  $  -         199
distribution payable
                                 --------  --------
                                 ----      ----
Other long term liabilities      249,142   -
                                 --------  --------
                                 ----      ----
Partners' equity -
 General partner                 5,027     19,410
 Limited partners                328,439   501,676
                                 --------  --------
                                 ----      ----
   Total partners' equity        333,466   521,086
                                 --------  --------
                                 ----      ----
                              $  582,608   521,285
                                 =======   =======

<PAGE>

              Southwest Oil and Gas Income Fund VIII-A, L.P.
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended    Nine Months
                                                          Ended
                                   September 30,      September 30,
                                   2003      2002     2003     2002
                                           (Restate           (Restat
                                              d)                ed)
                                   ----      ----     ----     ----
Revenues
-------------
Oil and Gas                   $  339,578   293,871   1,088,9  749,848
                                                     56
Interest                         431       195       1,059    413
Miscellaneous settlement         -         292       46       600
                                 --------  --------  -------  -------
                                 --        --        -----    ---
                                 340,009   294,358   1,090,0  750,861
                                                     61
                                 --------  --------  -------  -------
                                 --        --        -----    ---
Expenses
------------
Production                       159,948   177,821   495,872  482,289
General and administrative       28,090    26,882    88,156   78,504
Depreciation, depletion and      3,000     7,000     15,000   21,000
amortization
Accretion of asset retirement    4,701     -         16,403   -
obligation
                                 --------  --------  -------  -------
                                 --        --        -----    ---
                                 195,739   211,703   615,431  581,793
                                 --------  --------  -------  -------
                                 --        --        -----    ---
Net income from continued        144,270   82,655    474,630  169,068
operations

Results from discontinued
operations-
 sale of oil and gas leases -    107       8,972     20,451   20,440
See Note 5
                                 --------  --------  -------  -------
                                 --        --        -----    ---
Net income before cumulative     144,377   91,627    495,081  189,508
effects

Cumulative effect of change
in accounting
 principle - SFAS No. 143 -      -         -         (158,91  -
See Note 3                                           9)
Cumulative effect of change
in accounting principle
 - change in depletion method    -         -         -        (5,000)
- See Note 4
                                 --------  --------  -------  -------
                                 --        --        -----    ---
Net income                    $  144,377   91,627    336,162  184,508
                                 ======    ======    =======  ======
                                                                 continued
<PAGE>

              Southwest Oil and Gas Income Fund VIII-A, L.P.
                         Statements of Operations
                                (unaudited)

                                 Three Months Ended  Nine Months Ended
                                   September 30,       September 30,
                                   2003      2002      2003      2002
                                           (Restate            (Restat
                                              d)                 ed)
                                   ----      ----      ----      ----
Net income allocated to:
 Managing General Partner     $  14,738    9,863     35,116    21,051
                                 ======    ======    =======   ======
 Limited Partners             $  129,639   81,764    301,046   163,457
                                 ======    ======    =======   ======
  Per limited partner unit
before discontinued
   operations and cumulative  $    9.53
effect                                     5.42      31.31     11.04
  Discontinued operations per       .01         .59
limited partner unit                                 1.35      1.35
  Cumulative effects per              -         -    (10.52)     (.37)
limited partner unit
                                 --------  --------  --------  -------
                                 --        --        ----      ---
  Per limited partner unit    $    9.54
                                           6.01      22.14     12.02
                                 ======    ======    =======   ======
Pro forma amounts assuming
change is applied
 retroactively (See Note 3):
 Net income before cumulative $       -    85,183         -    170,175
effect
                                 ======    ======    =======   ======
  Per limited partner unit    $       -                   -
(13,596.0)                                 5.58                11.11
                                 ======    ======    =======   ======
 Net income                   $       -    85,183         -    165,175
                                 ======    ======    =======   ======
  Per limited partner unit    $       -                   -
(13,596.0)                                 5.58                10.74
                                 ======    ======    =======   ======

<PAGE>
              Southwest Oil and Gas Income Fund VIII-A, L.P.
                         Statements of Cash Flows
                                (unaudited)

                                                    Nine Months Ended
                                                      September 30,
                                                     2003       2002
                                                             (Restated
                                                                 )
                                                     ----       ----
        Cash flows from operating activities
        Cash received from oil and gas sales   $  1,080,704  680,008
        Cash paid to suppliers                    (563,930)  (559,592)
        Cash received from discontinued           20,451     20,440
        operations
        Interest received                         1,059      413
        Miscellaneous settlement                  46         600
                                                  ---------  ---------
                                                  ---        ---
         Net cash provided by operating           538,330    141,869
        activities
                                                  ---------  ---------
                                                  ---        ---
        Cash flows from investing activities
        Sale of oil and gas property              110,169    -
        Additions to oil and gas properties       (11,313)   (38,592)
                                                  ---------  ---------
                                                  ---        ---
         Net cash provided by (used in)           98,856     (38,592)
        investing activities
                                                  ---------  ---------
                                                  ---        ---
        Cash flows used in financing
        activities
        Distributions to partners                 (523,981)  (81,975)
                                                  ---------  ---------
                                                  ---        ---
        Net increase (decrease) in cash and       113,205    21,302
        cash equivalents

        Beginning of period                       56,709     37,385
                                                  ---------  ---------
                                                  ---        ---
        End of period                          $  169,914    58,687
                                                  =======    =======
        Reconciliation of net income to net
        cash
        provided by operating activities

        Net income                             $  336,162    184,508
        Adjustments to reconcile net income
        to net
        cash provided by operating activities
        Depreciation, depletion and               15,000     21,000
        amortization
        Accretion of asset retirement             16,403     -
        obligation
        Cumulative effect of change in
        accounting
         principle - SFAS No. 143                 158,919    -
        Cumulative effect of change in
        accounting
         principle - change in depletion          -          5,000
        method
        (Increase) decrease in receivables        (8,252)    (69,840)
        Increase (decrease) in payables           20,098     1,201
                                                  ---------  ---------
                                                  ---        ---
        Net cash provided by operating         $  538,330    141,869
        activities
                                                  =======    =======
        Noncash investing and financing
        activities;
        Increase in oil and gas properties -
        Adoption
         of SFAS No. 143                       $  191,308    -
        Increase in oil and gas properties -
        SFAS No. 143
         Additional well due to farmout        $  168        -
        arrangement
        Decrease in oil and properties - SFAS
        No. 143
         Sale of property                      $  117,656
                                                  =======    =======
<PAGE>
               Southwest Oil & Gas Income Fund VIII-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

1.   Organization
     Southwest  Oil & Gas Income Fund VIII-A, L.P. was organized under  the
     laws of the state of Delaware on November 30, 1987, for the purpose of
     acquiring  producing oil and gas properties and to produce and  market
     crude oil and natural gas produced from such properties for a term  of
     50  years, unless terminated at an earlier date as provided for in the
     Partnership  Agreement.   The  Partnership  sells  its  oil  and   gas
     production  to  a  variety of purchasers with the prices  it  receives
     being  dependent  upon the oil and gas economy.  Southwest  Royalties,
     Inc.  serves  as  the Managing General Partner.  Revenues,  costs  and
     expenses are allocated as follows:
                              Limited   General
                              Partners  Partners
                              --------  --------
Interest  income on  capital  100%      -
contributions
Oil and gas sales             90%       10%
All other revenues            90%       10%
Organization  and   offering  100%      -
costs (1)
Amortization of organization  100%      -
costs
Syndication costs             100%      -
Property acquisition costs    100%      -
Gain/loss    on     property  90%       10%
disposition
Operating and administrative  90%       10%
costs (2)
Depreciation, depletion  and
amortization
 of oil and gas properties    100%      -
All other costs               90%       10%

          (1)All  organization  costs in excess of 3%  of  initial  capital
          contributions  will be paid by the Managing General  Partner  and
          will  be treated as a capital contribution.  The Partnership paid
          the  Managing  General Partner an amount equal to 3%  of  initial
          capital contributions for such organization costs.

          (2)Administrative costs in any year which exceed  2%  of  capital
          contributions shall be paid by the Managing General  Partner  and
          will be treated as a capital contribution.

2.   Summary of Significant Accounting Policies
     The  interim financial information as of September 30, 2003,  and  for
     the  three  and  nine months ended September 30, 2003,  is  unaudited.
     Certain  information  and footnote disclosures  normally  included  in
     financial  statements prepared in accordance with  generally  accepted
     accounting principles have been condensed or omitted in this Form 10-Q
     pursuant  to the rules and regulations of the Securities and  Exchange
     Commission.  However,  in  the opinion of  management,  these  interim
     financial  statements include all the necessary adjustments to  fairly
     present  the  results of the interim periods and all such  adjustments
     are  of  a normal recurring nature. The interim consolidated financial
     statements  should  be  read  in conjunction  with  the  Partnership's
     Amendment  No. 1 to its Annual Report on Form 10-K for the year  ended
     December 31, 2002, filed with SEC on November 10, 2003.

3.   Cumulative effect of change in accounting principle - SFAS No. 143
     On  January  1, 2003, the Partnership adopted Statement  of  Financial
     Accounting   Standards  No.  143,  Accounting  for  Asset   Retirement
     Obligations  ("SFAS No. 143").  Adoption of SFAS No. 143  is  required
     for  all  companies with fiscal years beginning after June  15,  2002.
     The new standard requires the Partnership to recognize a liability for
     the  present  value  of  all  legal obligations  associated  with  the
     retirement  of tangible long-lived assets and to capitalize  an  equal
     amount as a cost of the asset and depreciate the additional cost  over
     the  estimated  useful  life of the asset.  On January  1,  2003,  the
     Partnership    recorded   additional   costs,   net   of   accumulated
     depreciation,  of  approximately $191,308, a long  term  liability  of
     approximately  $350,227 and a loss of approximately $158,919  for  the
     cumulative  effect  on  depreciation  of  the  additional  costs   and
     accretion  expense  on  the liability related to expected  abandonment
     costs  of  its oil and natural gas producing properties.  At September
     30,  2003, the asset retirement obligation was $249,142. The  decrease
     in  the balance from January 1, 2003 is due to the sale of oil and gas
     properties,  which  decreased  the  asset  retirement  obligation   by
     $117,656  offset  slightly by accretion expense of  $16,403  plus  the
     addition of a new well due to a farmout arrangement for $168.  The pro
     forma  amounts for the three and nine months ended September 30, 2002,
     which  are  presented  on  the face of the statements  of  operations,
     reflect the effect of retroactive application of SFAS No. 143.

<PAGE>
               Southwest Oil & Gas Income Fund VIII-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

4.    Cumulative  effect  of change in accounting  principle  -  change  in
depletion method
     In  the  fourth  quarter of 2002, the Partnership changed  methods  of
     accounting  for  depletion  of capitalized costs  from  the  units-of-
     revenue  method to the units-of-production method.  The newly  adopted
     accounting  principle is preferable in the circumstances  because  the
     units-of-production method results in a better matching of  the  costs
     of  oil  and  gas production against the related revenue  received  in
     periods of volatile prices for production as have been experienced  in
     recent  periods.  Additionally, the units-of-production method is  the
     predominant  method used by full cost companies in  the  oil  and  gas
     industry,  accordingly, the change improves the comparability  of  the
     Partnership's   financial  statements  with  its  peer   group.    The
     Partnership   adopted  the  units-of-production  method  through   the
     recording  of a cumulative effect of a change in accounting  principle
     in  the  amount  of  $5,000  effective as of  January  1,  2002.   The
     Partnership's depletion for the three and nine months ended  September
     30,  2003  and  2002 has been calculated using the units-of-production
     method.  There was no effect due to the change in depletion method  on
     the quarter ended September 30, 2002.  The effect of the change on the
     nine  months  ended September 30, 2002 was to decrease  income  before
     cumulative effect of a change in accounting principle by $1,000  ($.07
     per  limited partner unit) and net income by $6,000 ($.44 per  limited
     partner unit).

5.   Discontinued Operations - Sale of oil and gas leases
     During the three months ended June 30, 2003, the Partnership sold  its
     interest  in  certain  oil,  gas and salt  water  disposal  wells  for
     $110,169  sales  proceeds  and retired $117,656  of  asset  retirement
     obligation  associated with the properties.  Since the Partnership  is
     under the full cost pool method of accounting, the sales proceeds  and
     asset  retirement obligation liability were taken against the oil  and
     gas  properties  asset account and therefore,  no  gain  or  loss  was
     recorded  and  shown on the statement of operations  as  part  of  the
     discontinued  operations.  Pursuant to the requirements  of  SFAS  No.
     144,  the historical operating results from these properties have been
     reported as discontinued operations in the accompanying statements  of
     operations.    The  following  table  summarizes  certain   historical
     operating information related to the discontinued operations:

                                  Three Months Ended       Nine Months Ended
                                   2003       2002         2003       2002

           Revenues              $    -     18,870       34,987    49,768
           Net income            107        8,972        20,451    20,440


<PAGE>
               Southwest Oil & Gas Income Fund VIII-A, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements

6.   September 30, 2002 Restatement
     During  the fourth quarter of 2002, the Partnership changed its method
     of  providing  for depletion from the units-of-revenue method  to  the
     units-of-production method as described in Note 4.

     This  change in the method used to implement the Partnership's  change
     in  the manner in which it determines depletion resulted in a decrease
     in the Partnership's previously reported net oil and gas properties of
     $6,000  from $337,313 to $331,313 as of December 31, 2002 and did  not
     effect the Partnership's 2002 cash flows from operations, investing or
     financing activities.

     The  change  had the following effects on the Statement of  Operations
     for the three and nine months ended September 30, 2002.

                                  Three Months Ended       Nine Months Ended
                                            Previous               Previously
                                               ly
                                 Restated   Reported     Restated   Reported
         Depreciation,
         depletion and
          amortization           $7,000     $7,000       21,000    20,000
         Income before           91,627     91,627       189,508   190,508
         cumulative effect
       Cumulative effect of
         change in
          accounting principle   -          -            (5,000)   -
         Net income              91,627     91,627       184,508   190,508
         Net income allocated
         to:
         Managing General        9,863      9,863        21,051    21,051
         Partner
         Limited partners        81,764     81,764       163,457   169,457
          Income per limited
         partner
            unit before            6.01                                12.46
         cumulative effect                  6.01         12.39
          Cumulative effect
         per limited
            partner unit              -          -        (.37)         -
          Net income per
         limited
            partner unit           6.01                                12.46
                                            6.01         12.02


<PAGE>
Item 2.   Management's  Discussion and Analysis of Financial Condition  and
        Results of Operations

General
Southwest  Oil & Gas Income Fund VIII-A, L.P. was organized as  a  Delaware
limited  partnership  on November 30, 1987. The offering  of  such  limited
partnership interests began on March 31, 1988, minimum capital requirements
were  met  on July 6, 1988, and the offering concluded on March  31,  1989,
with total limited partner contributions of $6,798,000.

The  Partnership was formed to acquire interests in producing oil  and  gas
properties,  to produce and market crude oil and natural gas produced  from
such properties, and to distribute the net proceeds from operations to  the
limited  and  general partners.  Net revenues from producing  oil  and  gas
properties are not reinvested in other revenue producing assets  except  to
the extent that production facilities and wells are improved or reworked or
where methods are employed to improve or enable more efficient recovery  of
oil and gas reserves.

Increases   or   decreases   in  Partnership   revenues   and,   therefore,
distributions  to partners will depend primarily on changes in  the  prices
received  for production, changes in volumes of production sold,  increases
and  decreases  in  lease operating expenses, enhanced  recovery  projects,
offset  drilling  activities pursuant to farm-out  arrangements,  sales  of
properties,  and  the depletion of wells.  Since wells deplete  over  time,
production can generally be expected to decline from year to year.

Well  operating costs and general and administrative costs usually decrease
with   production   declines;  however,  these  costs  may   not   decrease
proportionately.  Net income available for distribution to the partners  is
therefore expected to fluctuate in later years based on these factors.

Based  on current conditions, management anticipates performing development
drilling  projects and workovers during the years 2003 and 2004 to  enhance
production.  The Partnership may have an increase in production volumes for
the  years  2003  and  2004, otherwise, the Partnership  will  most  likely
experience the historical production decline, which has approximated 8% per
year.

Oil and Gas Properties
Oil  and  gas  properties  are accounted for at cost  under  the  full-cost
method.  Under this method, all productive and nonproductive costs incurred
in  connection with the acquisition, exploration and development of oil and
gas  reserves  are capitalized.  Gain or loss on the sale of  oil  and  gas
properties  is not recognized unless significant oil and gas  reserves  are
involved.

In  the  fourth  quarter  of  2002,  the  Partnership  changed  methods  of
accounting  for  depletion of capitalized costs from  the  units-of-revenue
method  to  the  units-of-production method.  The newly adopted  accounting
principle   is  preferable  in  the  circumstances  because  the  units-of-
production method results in a better matching of the costs of oil and  gas
production  against  the related revenue received in  periods  of  volatile
prices   for  production  as  have  been  experienced  in  recent  periods.
Additionally, the units-of-production method is the predominant method used
by full cost companies in the oil and gas industry, accordingly, the change
improves  the comparability of the Partnership's financial statements  with
its peer group.

Should the net capitalized costs exceed the estimated present value of  oil
and gas reserves, discounted at 10%, such excess costs would be charged  to
current  expense.  As of September 30, 2003, the net capitalized costs  did
not exceed the estimated present value of oil and gas reserves.

<PAGE>
Critical Accounting Policies

Full cost ceiling calculations The Partnership follows the full cost method
of  accounting  for  its  oil and gas properties.   The  full  cost  method
subjects  companies to quarterly calculations of a "ceiling", or limitation
on  the  amount of properties that can be capitalized on the balance sheet.
If  the  Partnership's capitalized costs are in excess  of  the  calculated
ceiling, the excess must be written off as an expense.

The  Partnership's discounted present value of its proved oil  and  natural
gas  reserves  is  a  major  component  of  the  ceiling  calculation,  and
represents  the  component  that requires the  most  subjective  judgments.
Estimates  of  reserves are forecasts based on engineering data,  projected
future  rates  of  production and the timing of future  expenditures.   The
process  of  estimating oil and natural gas reserves  requires  substantial
judgment,  resulting  in  imprecise determinations,  particularly  for  new
discoveries.   Different reserve engineers may make different estimates  of
reserve  quantities  based  on the same data.   The  Partnership's  reserve
estimates are prepared by outside consultants.

The  passage  of  time  provides  more  qualitative  information  regarding
estimates of reserves, and revisions are made to prior estimates to reflect
updated  information.   However,  there  can  be  no  assurance  that  more
significant  revisions  will not be necessary in  the  future.   If  future
significant  revisions  are  necessary  that  reduce  previously  estimated
reserve quantities, it could result in a full cost property writedown.   In
addition to the impact of these estimates of proved reserves on calculation
of  the  ceiling,  estimates  of proved reserves  are  also  a  significant
component of the calculation of DD&A.

While  estimating  the  quantities of proved reserves  require  substantial
judgment,  the associated prices of oil and natural gas reserves  that  are
included  in  the discounted present value of the reserves do  not  require
judgment.  The ceiling calculation dictates that prices and costs in effect
as  of the last day of the period are generally held constant indefinitely.
Because  the ceiling calculation dictates that prices in effect as  of  the
last  day  of  the  applicable quarter are held constant indefinitely,  the
resulting  value  may  not be indicative of the  true  fair  value  of  the
reserves.  Oil and natural gas prices have historically been cyclical  and,
on  any particular day at the end of a quarter, can be either substantially
higher or lower than the Partnership's long-term price forecast that  is  a
barometer for true fair value.

In  the  fourth  quarter  of  2002,  the  Partnership  changed  methods  of
accounting  for  depletion of capitalized costs from  the  units-of-revenue
method  to  the  units-of-production method.  The newly adopted  accounting
principle   is  preferable  in  the  circumstances  because  the  units-of-
production method results in a better matching of the costs of oil and  gas
production  against  the related revenue received in  periods  of  volatile
prices   for  production  as  have  been  experienced  in  recent  periods.
Additionally, the units-of-production method is the predominant method used
by full cost companies in the oil and gas industry, accordingly, the change
improves  the comparability of the Partnership's financial statements  with
its peer group.


<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended September 30, 2003 and 2002

The  following  table  provides certain information  regarding  performance
factors for the quarters ended September 30, 2003 and 2002:

                               Three Months
                                  Ended         Percenta
                                                   ge
                              September 30,     Increase
                              2003      2002    (Decreas
                                                   e)
                              ----      ----    --------
                                                   --
Average    price    per  $   29.25              9%
barrel of oil                         26.78
Average  price per  mcf  $    4.67              54%
of gas                                3.03
Oil    production    in     9,900     10,300    (4%)
barrels
Gas production in mcf       10,700    12,200    (12%)
Gross   oil   and   gas  $  339,578   293,871   16%
revenue
Net oil and gas revenue  $  179,630   116,050   55%
Partnership              $  228,782   50,000    358%
distributions
Limited         partner  $  208,782   45,000    364%
distributions
Per  unit  distribution
to limited
 partners                $   15.36              364%
                                      3.31
Number    of    limited     13,596    13,596
partner units

Revenues

The  Partnership's oil and gas revenues increased to $339,578 from $293,871
for  the  quarters  ended  September 30, 2003 and  2002,  respectively,  an
increase  of  16%.  The principal factors affecting the comparison  of  the
quarters ended September 30, 2003 and 2002 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended September 30, 2003 as  compared  to
    the  quarter  ended  September 30, 2002 by 9%,  or  $2.47  per  barrel,
    resulting  in  an increase of approximately $24,500 in  revenues.   Oil
    sales  represented  85% of total oil and gas sales during  the  quarter
    ended  September 30, 2003 as compared to 88% during the  quarter  ended
    September 30, 2002.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 54%, or $1.64 per mcf, resulting in
    an increase of approximately $17,500 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $42,000.  The market price
    for  oil  and gas has been extremely volatile over the past decade  and
    management  expects a certain amount of volatility to continue  in  the
    foreseeable future.

<PAGE>

2.  Oil  production decreased approximately 400 barrels or  4%  during  the
    quarter  ended  September 30, 2003 as compared  to  the  quarter  ended
    September 30, 2002, resulting in a decrease of approximately $10,700 in
    revenues.

    Gas production decreased approximately 1,500 mcf or 12% during the same
    period, resulting in a decrease of approximately $4,500 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $15,200.  The decrease in gas production is  primarily  a
    rapid decline on one property.

Costs and Expenses

Total  costs  and  expenses decreased to $195,739  from  $211,703  for  the
quarters ended September 30, 2003 and 2002, respectively, a decrease of 8%.
The  decrease is the result of lower depletion expense and lease  operating
costs,  partially  offset  by  the addition of  accretion  expense  and  an
increase in general and administrative expense.

1.    Lease  operating  costs  and production  taxes  were  10%  lower,  or
   approximately $17,900 less during the quarter ended September 30, 2003 as
   compared to the quarter ended September 30, 2002.

2.  General and administrative costs consist of independent accounting  and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner personnel costs.  General and administrative costs increased 4%
    or  approximately $1,200 during the quarter ended September 30, 2003 as
    compared to the quarter ended September 30, 2002.

3.  Depletion  expense decreased to $3,000 for the quarter ended  September
    30,  2003  from $7,000 for the same period in 2002.  This represents  a
    decrease  of  57%.   In  the fourth quarter of  2002,  the  Partnership
    changed  methods of accounting for depletion of capitalized costs  from
    the  units-of-revenue  method to the units-of-production  method.   The
    newly  adopted  accounting principle is preferable in the circumstances
    because the units-of-production method results in a better matching  of
    the  costs  of  oil  and  gas production against  the  related  revenue
    received  in  periods of volatile prices for production  as  have  been
    experienced  in  recent periods.  Additionally, the units-of-production
    method is the predominant method used by full cost companies in the oil
    and gas industry, accordingly, the change improves the comparability of
    the  Partnership's financial statements with its peer group.  There was
    no  effect due to the change in depletion method for the quarter  ended
    September   30,  2002(See  Note  4  of  the  notes  to  the   financial
    statements).  The  contributing factor to  the  decrease  in  depletion
    expense is in relation to the BOE depletion rate for the quarter  ended
    September 30, 2003, which was $.26 applied to 11,683 BOE as compared to
    $.57  applied  to 12,333 BOE for the same period.  The decline  is  due
    largely to the sale of two oil and gas properties.


<PAGE>

B.   General Comparison of the Nine Month Periods Ended September 30,  2003
and 2002

The  following  table  provides certain information  regarding  performance
factors for the nine month periods ended September 30, 2003 and 2002:

                                    Nine Months
                                       Ended         Percenta
                                                        ge
                                   September 30,     Increase
                                   2003      2002    (Decreas
                                                        e)
                                   ----      ----    --------
                                                        --
Average price per barrel  of  $    29.70             26%
oil                                        23.53
Average price per mcf of gas  $     5.18             79%
                                           2.89
Oil production in barrels        31,700    29,600    7%
Gas production in mcf            35,200    35,700    (1%)
Gross oil and gas revenue     $  1,088,95  749,848   45%
                                 6
Net oil and gas revenue       $  593,084   267,559   122%
Partnership distributions     $  523,782   82,000    539%
Limited              partner  $  474,282   73,800    543%
distributions
Per  unit  distribution   to
limited
 partners                     $    34.88             543%
                                           5.43
Number  of  limited  partner     13,596    13,596
units

Revenues

The  Partnership's  oil  and  gas revenues  increased  to  $1,088,956  from
$749,848   for  the  nine  months  ended  September  30,  2003  and   2002,
respectively,  an  increase of 45%.  The principal  factors  affecting  the
comparison  of  the nine months ended September 30, 2003 and  2002  are  as
follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the nine months ended September 30, 2003 as  compared
    to  the  nine  months ended September 30, 2002 by  26%,  or  $6.17  per
    barrel, resulting in an increase of approximately $195,600 in revenues.
    Oil  sales represented 84% of total oil and gas sales during  the  nine
    months  ended  September 30, 2003 as compared to 87%  during  the  nine
    months ended September 30, 2002.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 79%, or $2.29 per mcf, resulting in
    an increase of approximately $80,600 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $276,200.   The  market
    price  for oil and gas has been extremely volatile over the past decade
    and  management expects a certain amount of volatility to  continue  in
    the foreseeable future.

<PAGE>

2. Oil  production increased approximately 2,100 barrels or 7%  during  the
   nine  months  ended September 30, 2003 as compared to  the  nine  months
   ended  September  30,  2002, resulting in an increase  of  approximately
   $49,400 in revenues.

   Gas  production  decreased approximately 500 mcf or 1% during  the  same
   period, resulting in a decrease of approximately $1,400 in revenues.

   The  net  total increase in revenues due to the change in production  is
   approximately $48,000.

Costs and Expenses

Total  costs and expenses increased to $615,431 from $581,793 for the  nine
months ended September 30, 2003 and 2002, respectively, an increase of  6%.
The  increase  is  the result of the addition of accretion expense,  higher
general  and  administrative expense and lease operating  costs,  partially
offset by a decrease in depletion expense.

1. Lease   operating  costs  and  production  taxes  were  3%  higher,   or
   approximately  $13,600 more during the nine months ended  September  30,
   2003 as compared to the nine months ended September 30, 2002.

2.  General and administrative costs consist of independent accounting  and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner  personnel costs.  General and administrative  costs  increased
    12%  or approximately $9,700 during the nine months ended September 30,
    2003  as  compared to the nine months ended September  30,  2002.   The
    increase in general and administrative expense is due to an increase in
    independent accounting review and audit fees.

3.  Depletion  expense  decreased to $15,000  for  the  nine  months  ended
    September  30,  2003 from $21,000 for the same period  in  2002.   This
    represents  a  decrease of 29%.  In the fourth  quarter  of  2002,  the
    Partnership  changed methods of accounting for depletion of capitalized
    costs  from  the  units-of-revenue method  to  the  units-of-production
    method.   The newly adopted accounting principle is preferable  in  the
    circumstances  because  the units-of-production  method  results  in  a
    better  matching  of  the costs of oil and gas production  against  the
    related  revenue received in periods of volatile prices for  production
    as have been experienced in recent periods.  Additionally, the units-of-
    production method is the predominant method used by full cost companies
    in  the  oil  and  gas industry, accordingly, the change  improves  the
    comparability of the Partnership's financial statements with  its  peer
    group.   The effect of this change in method was to increase  depletion
    expense  for  the nine months ended September 30, 2002  by  $1,000  and
    decrease  net income for the nine months ended September  30,  2002  by
    $6,000(See  Note  4  of  the notes to the financial  statements).   The
    contributing factor to the decrease in depletion expense is in relation
    to the BOE depletion rate for the nine months ended September 30, 2003,
    which  was  $.40 applied to 37,567 BOE as compared to $.59  applied  to
    35,550  BOE  for the same period.  This decline is due largely  to  the
    sale of two oil and gas properties.

Cumulative effect of change in accounting principle
On  January  1,  2003,  the  Partnership  adopted  Statement  of  Financial
Accounting  Standards No. 143, Accounting for Asset Retirement  Obligations
("SFAS  No. 143").  Adoption of SFAS No. 143 is required for all  companies
with fiscal years beginning after June 15, 2002.  The new standard requires
the Partnership to recognize a liability for the present value of all legal
obligations  associated with the retirement of tangible  long-lived  assets
and to capitalize an equal amount as a cost of the asset and depreciate the
additional cost over the estimated useful life of the asset.  On January 1,
2003,  the  Partnership  recorded  additional  costs,  net  of  accumulated
depreciation,  of  approximately  $191,308,  a  long  term   liability   of
approximately  $350,227  and  a  loss of  approximately  $158,919  for  the
cumulative  effect  on depreciation of the additional costs  and  accretion
expense  on the liability related to expected abandonment costs of its  oil
and  natural  gas producing properties.  At September 30, 2003,  the  asset
retirement  obligation  was  $249,142. The decrease  in  the  balance  from
January  1,  2003  is  due  to the sale of oil and  gas  properties,  which
decreased  the asset retirement obligation by $117,656 offset  slightly  by
accretion  expense  of $16,403 plus the addition of a new  well  due  to  a
farmout arrangement for $168.  The pro forma amounts for the three and nine
months  ended September 30, 2002, which are presented on the  face  of  the
statements of operations, reflect the effect of retroactive application  of
SFAS No. 143.




<PAGE>

Liquidity and Capital Resources

The  primary source of cash is from operations, the receipt of income  from
interests in oil and gas properties.  The Partnership knows of no  material
change, nor does it anticipate any such change.

Cash flows provided by operating activities were approximately $538,300  in
the  nine  months  ended  September 30, 2003 as compared  to  approximately
$141,900  in the nine months ended September 30, 2002.  The primary  source
of the 2003 cash flow from operating activities was profitable operations.

Cash  flows  provided by (used in) investing activities were  approximately
$98,900  in  the  nine  months ended September  30,  2003  as  compared  to
approximately $(38,600) in the nine months ended September 30,  2002.   The
principle  source of the 2003 cash flow from investing activities  was  the
sale of oil and gas properties.

Cash flows used in financing activities were approximately $524,000 in  the
nine  months ended September 30, 2003 as compared to approximately  $82,000
in  the  nine  months ended September 30, 2002.  The only use in  financing
activities was the distributions to partners.

Total  distributions during the nine months ended September 30,  2003  were
$523,782  of  which  $474,282 was distributed to the limited  partners  and
$49,500  to  the  general partners.  The per unit distribution  to  limited
partners during the nine months ended September 30, 2003 was $34.88.  Total
distributions during the nine months ended September 30, 2002 were  $82,000
of  which $73,800 was distributed to the limited partners and $8,200 to the
general partners.  The per unit distribution to limited partners during the
nine months ended September 30, 2002 was $5.43.

The  sources  for  the  2003 distributions of $523,782  were  oil  and  gas
operations  of  approximately  $538,300 and  the  change  in  oil  and  gas
properties  of  approximately  $98,900,  resulting  in  excess   cash   for
contingencies  or  subsequent  distributions.  The  sources  for  the  2002
distributions  of  $82,000  were oil and gas  operations  of  approximately
$141,900  and  the  change  in  oil  and gas  properties  of  approximately
$(38,600),  resulting  in  excess  cash  for  contingencies  or  subsequent
distributions.

Since  inception  of  the  Partnership, cumulative  cash  distributions  of
$9,109,706  have  been  made to the partners.  As of  September  30,  2003,
$8,246,485 or $606.54 per limited partner unit has been distributed to  the
limited partners, representing a 100% return of the capital and 21%  return
on capital contributed.

As  of  September 30, 2003, the Partnership had approximately  $291,300  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual  commitments.  Although the partnership  held  many  long-lived
properties   at  inception,  because  of  the  restrictions   on   property
development  imposed by the partnership agreement, the  Partnership  cannot
develop   its   non  producing  properties,  if  any.   Without   continued
development,  the producing reserves continue to deplete.  Accordingly,  as
the  Partnership's properties have matured and depleted, the net cash flows
from  operations  for  the  partnership has steadily  declined,  except  in
periods  of  substantially  increased commodity  pricing.   Maintenance  of
properties  and administrative expenses for the Partnership are  increasing
relative to production.  As the properties continue to deplete, maintenance
of  properties  and administrative costs as a percentage of production  are
expected to continue to increase.

The  Managing General Partner has examined various alternatives to  address
the  issue of depleting producing reserves.  Continuing operations  exposes
the   partnership  to  an  inevitable  decline  in  operating  results  and
distributions  of  cash.   Liquidating  the  partnership  would  result  in
immediate  realization of cash for limited partners,  but  prices  paid  by
purchasers  of Partnership property in liquidation would likely  include  a
substantial discount for risks and uncertainties of future cash  flows,  as
well  as any development risks.  After reviewing various alternatives,  the
Managing General Partner initiated a plan to merge the Partnership  and  20
other limited partnerships with and into the Managing General Partner.   On
October  17,  2002,  the  Managing General  Partner  filed  a  Registration
Statement on Form S-4 with the Securities and Exchange Commission  relating
to  this proposed merger.  There is no assurance, however, that this merger
will  be consummated.  Currently the Managing General Partner is evaluating
whether or not to continue to pursue the proposed merger.


<PAGE>
Liquidity - Managing General Partner
In  previous  reports  the Partnership provided that the  Managing  General
Partner  had  $124.0  million  of principal  scheduled  to  mature  between
December 31, 2002 and December 31, 2004.  Subsequent to September 30,  2003
the   Managing  General  Partner  refinanced  the  majority  of  its   debt
obligations and currently has $71.7 million in debt scheduled to mature  on
June  1, 2006 and $40.0 million in debt scheduled to mature on October  15,
2008.   The  Managing General Partner believes that it  has  adequate  cash
flows to meet its debt principal maturities scheduled for 2004.

Recent Accounting Pronouncements

The  FASB  has  issued Statement No. 143 "Accounting for  Asset  Retirement
Obligations" which establishes requirements for the accounting of  removal-
type  costs  associated with asset retirements.  The standard is  effective
for  fiscal  years beginning after June 15, 2002, with earlier  application
encouraged.   This statement has been adopted by the Partnership  effective
January 1, 2003.  The transition adjustment resulting from the adoption  of
SFAS  No.  143  has been reported as a cumulative effect  of  a  change  in
accounting principle.

In  April 2003, the FASB issued Statement of Financial Accounting Standards
No.  149,  Amendment  of  Statement No. 133 on Derivative  Instruments  and
Hedging Activities ("SFAS No. 149").  SFAS No. 149 amendments require  that
contracts  with  comparable  characteristics be  accounted  for  similarly,
clarifies   when   a  contract  with  an  initial  investment   meets   the
characteristic  of  a  derivative and clarifies when a derivative  requires
special  reporting  in  the  statement of cash  flows.   SFAS  No.  149  is
effective  for  hedging relationships designated and for contracts  entered
into or modified after June 30, 2003, except for provisions that relate  to
SFAS  No. 133 Statement Implementation Issues that have been effective  for
fiscal  quarters  prior to June 15, 2003, should be applied  in  accordance
with  their  respective effective dates and certain provisions relating  to
forward  purchases or sales of when-issued securities or  other  securities
that  do not yet exist, should be applied to existing contracts as well  as
new contracts entered into after June 30, 2003.  Assessment by the Managing
General  Partner  revealed this pronouncement to  have  no  impact  on  the
Partnership.

In  May  2003, the FASB issued Statement of Financial Accounting  Standards
No.150,  Accounting for Certain Financial Instruments with  Characteristics
of  both  Liabilities  and  Equity  ("SFAS  150").   SFAS  150  establishes
standards  for  how  an  issuer classifies and measures  certain  financial
instruments  with  characteristics of  both  liabilities  and  equity.   It
requires that an issuer classify a financial instrument that is within  the
scope of SFAS 150 as a liability (or an asset in some circumstances).  Many
of those instruments were previously classified as equity.  The application
of  SFAS 150 is not expected to have a material effect on the Partnership's
consolidated  financial  statements.   This  Statement  is  effective   for
financial  instruments entered into or modified after  May  31,  2003,  and
otherwise  is  effective  at  the beginning of  the  first  interim  period
beginning after June 15, 2003.


<PAGE>
Item 3.   Quantitative and Qualitative Disclosures About Market Risk

The  Partnership  is  not a party to any derivative or embedded  derivative
instruments.

Item 4.   Controls and Procedures

(a)   Evaluation  of  Disclosure  Controls  and  Procedures.   The   senior
management of the Partnership's Managing General Partner is responsible for
establishing and maintaining a system of disclosure controls and procedures
(as defined in Rule 13a-14 and 15d-14 under the Securities Exchange Act  of
1934 (the "Exchange Act")) designed to ensure that information required  to
be  disclosed  by the Partnership in the reports that it files  or  submits
under  the  Exchange Act is recorded, processed, summarized  and  reported,
within   the  time  periods  specified  in  the  Securities  and   Exchange
Commission's rules and forms.  Disclosure controls and procedures  include,
without  limitation,  controls  and  procedures  designed  to  ensure  that
information required to be disclosed by the issuer in the reports  that  it
files or submits under the Exchange Act is accumulated and communicated  to
the  issuer's  management,  including its principal  executive  officer  of
officers  and principal financial officer or officers, or person performing
similar  functions,  as  appropriate to allow  timely  decisions  regarding
required disclosure.

In  accordance  with Exchange Act Rules 13a-15 and 15d-15, the  Partnership
carried  out  an evaluation, with the participation of the Chief  Executive
Officer  and  Chief Financial Officer of the Managing General  Partner,  as
well as other key members of the Managing General Partner's management,  of
the  effectiveness of the Partnership's disclosure controls and  procedures
as  of  the  end  of  the  period covered by this report.   Based  on  that
evaluation,  the  Managing General Partner's Chief  Executive  Officer  and
Chief   Financial  Officer  concluded  that  the  Partnership's  disclosure
controls and procedures were effective, as of the end of the period covered
by  this  report, to provide reasonable assurance that information required
to  be disclosed in the Partnership's reports filed or submitted under  the
Exchange  Act  is recorded, processed, summarized and reported  within  the
time  periods  specified in the Securities and Exchange Commission's  rules
and forms.

(b)  Changes in Internal Controls.  There have not been any changes in  the
Partnership's  internal  controls over financial  reporting  identified  in
connection  with  the evaluation described above that occurred  during  the
Partnership's  last  fiscal  quarter that has materially  affected,  or  is
reasonably  likely  to  materially affect,  these  internal  controls  over
financial reporting.

<PAGE>
                        PART II - OTHER INFORMATION


Item 1.  Legal Proceedings

         None

Item 2.  Changes in Securities

         None

Item 3.  Defaults Upon Senior Securities

         None

Item 4.  Submission of Matter to a Vote of Security Holders

         None

Item 5.  Other Information

         None

Item 6.  Exhibits and Reports on Form 8-K

          (a)  Exhibits:

               31.1 Rule 13a-14(a)/15d-14(a) Certification
31.2 Rule 13a-14(a)/15d-14(a) Certification
               32.1 Certification of Chief Executive Officer Pursuant to
 18 U.S.C. Section
                  1350, as
                  adopted  Pursuant  to Section 906 of  the  Sarbanes-Oxley
                  Act of 2002
               32.2 Certification of Chief Financial Officer Pursuant to
 18 U.S.C. Section
                  1350, as
                  adopted Pursuant to Section 906 of the Sarbanes-Oxley Act
               of 2002

          (b)  No reports on Form 8-K were filed during the quarter
for which this
               report is filed.


<PAGE>

                                SIGNATURES


Pursuant  to the requirements of the Securities Exchange Act of  1934,  the
registrant  has duly caused this report to be signed on its behalf  by  the
undersigned thereunto duly authorized.

                                   Southwest Oil and Gas Income Fund VIII-
                                   A, L.P.
                                   a Delaware limited partnership

                                   By:  Southwest Royalties, Inc.
                                        Managing General Partner


                                   By:  /s/ Bill E. Coggin
                                        ------------------------------
                                        Bill E. Coggin, Executive Vice
President
                                        and Chief Financial Officer

Date:     November 14, 2003

<PAGE>

                    SECTION 302 CERTIFICATION                Exhibit 31.1


I, H.H. Wommack, III, certify that:

1.  I have reviewed this quarterly report on Form 10-Q of Southwest Oil and
Gas Income Fund VIII-A, L.P.

2.Based  on my knowledge, this report does not contain any untrue statement
  of  a  material fact or omit to state a material fact necessary  to  make
  the  statements  made,  in light of the circumstances  under  which  such
  statements  were made, not misleading with respect to the period  covered
  by this report;

3.Based  on  my  knowledge, the financial statements, and  other  financial
  information  included  in  this report, fairly present  in  all  material
  respects  the financial condition, results of operations and  cash  flows
  of the registrant as of, and for, the periods presented in this report;

4.The  registrant's other certifying officer(s) and I are  responsible  for
  establishing  and  maintaining disclosure  controls  and  procedures  (as
  defined  in  Exchange  Act  Rules 13a-15(e) and  15-15(e))  and  internal
  control  over financial reporting (as defined in Exchange Act Rules  13a-
  15(f) and 15d-15(f) for the registrant and have:

  a)Designed  such  disclosure  controls and  procedures,  or  caused  such
     disclosure   controls  and  procedures  to  be  designed   under   our
     supervision,  to  ensure  that material information  relating  to  the
     registrant, including its consolidated subsidiaries, is made known  to
     us  by others within those entities, particularly during the period in
     which this report is being prepared;

  b)Designed  such  internal control over financial  reporting,  or  caused
     such  internal  control over financial reporting to be designed  under
     our   supervision,  to  provide  reasonable  assurance  regarding  the
     reliability  of financial reporting and the preparation  of  financial
     statements for external purposes in accordance with generally accepted
     accounting principles;

  c)Evaluated  the  effectiveness of the registrant's  disclosure  controls
     and  procedures and presented in this report our conclusions about the
     effectiveness of the disclosure controls and procedures, as of the end
     of the period covered by this report based on such evaluation; and

  d)Disclosed  in  this  report  any change in  the  registrant's  internal
     control over financial reporting that occurred during the registrant's
     most recent fiscal quarter (the registrant's fourth fiscal quarter  in
     the  case  of  an annual report) that has materially affected,  or  is
     reasonably  likely  to  materially affect, the  registrant's  internal
     control over financial reporting; and

5.The  registrant's other certifying officer(s) and I have disclosed, based
  on  our  most  recent  evaluation  of  internal  control  over  financial
  reporting,  to  the  registrant's auditors and  the  audit  committee  of
  registrant's  board  of directors (or persons performing  the  equivalent
  functions):

  a)All  significant deficiencies and material weaknesses in the design  or
     operation   of  internal  controls  over  financial  reporting   which
     reasonably  likely  to  adversely affect the registrant's  ability  to
     record, process, summarize and report financial information; and

  b)Any  fraud, whether or not material, that involves management or  other
     employees  who  have  a significant role in the registrant's  internal
     controls over financial reporting.


Date:  November 14, 2003           /s/ H.H. Wommack, III
                                   H. H. Wommack, III
                                    Chairman, President and Chief Executive
Officer
                                   of Southwest Royalties, Inc., the
                                   Managing General Partner of
                                    Southwest Oil & Gas Income Fund  VII-A,
L.P.



<PAGE>
                    SECTION 302 CERTIFICATION                Exhibit 31.2


I, Bill E. Coggin, certify that:

1.  I have reviewed this quarterly report on Form 10-Q of Southwest Oil and
Gas Income Fund VIII-A, L.P.

2.Based  on my knowledge, this report does not contain any untrue statement
  of  a  material fact or omit to state a material fact necessary  to  make
  the  statements  made,  in light of the circumstances  under  which  such
  statements  were made, not misleading with respect to the period  covered
  by this report;

3.Based  on  my  knowledge, the financial statements, and  other  financial
  information  included  in  this report, fairly present  in  all  material
  respects  the financial condition, results of operations and  cash  flows
  of the registrant as of, and for, the periods presented in this report;

4.The  registrant's other certifying officer(s) and I are  responsible  for
  establishing  and  maintaining disclosure  controls  and  procedures  (as
  defined  in  Exchange  Act  Rules 13a-15(e) and  15-15(e))  and  internal
  control  over financial reporting (as defined in Exchange Act Rules  13a-
  15(f) and 15d-15(f) for the registrant and have:

  a)Designed  such  disclosure  controls and  procedures,  or  caused  such
     disclosure   controls  and  procedures  to  be  designed   under   our
     supervision,  to  ensure  that material information  relating  to  the
     registrant, including its consolidated subsidiaries, is made known  to
     us  by others within those entities, particularly during the period in
     which this report is being prepared;

  b)Designed  such  internal control over financial  reporting,  or  caused
     such  internal  control over financial reporting to be designed  under
     our   supervision,  to  provide  reasonable  assurance  regarding  the
     reliability  of financial reporting and the preparation  of  financial
     statements for external purposes in accordance with generally accepted
     accounting principles;

  c)Evaluated  the  effectiveness of the registrant's  disclosure  controls
     and  procedures and presented in this report our conclusions about the
     effectiveness of the disclosure controls and procedures, as of the end
     of the period covered by this report based on such evaluation; and

  d)Disclosed  in  this  report  any change in  the  registrant's  internal
     control over financial reporting that occurred during the registrant's
     most recent fiscal quarter (the registrant's fourth fiscal quarter  in
     the  case  of  an annual report) that has materially affected,  or  is
     reasonably  likely  to  materially affect, the  registrant's  internal
     control over financial reporting; and

5.The  registrant's other certifying officer(s) and I have disclosed, based
  on  our  most  recent  evaluation  of  internal  control  over  financial
  reporting,  to  the  registrant's auditors and  the  audit  committee  of
  registrant's  board  of directors (or persons performing  the  equivalent
  functions):

  a)All  significant deficiencies and material weaknesses in the design  or
     operation   of  internal  controls  over  financial  reporting   which
     reasonably  likely  to  adversely affect the registrant's  ability  to
     record, process, summarize and report financial information; and

  b)Any  fraud, whether or not material, that involves management or  other
     employees  who  have  a significant role in the registrant's  internal
     controls over financial reporting.


Date:  November 14, 2003           /s/ Bill E. Coggin
                                   Bill E. Coggin
                                   Executive Vice President
                                   and Chief Financial Officer of
                                   Southwest Royalties, Inc., the
                                   Managing General Partner of
                                    Southwest Oil & Gas Income Fund  VII-A,
L.P.



<PAGE>

                         CERTIFICATION PURSUANT TO
                               Exhibit 32.1
                          19 U.S.C. SECTION 1350,
                          AS ADOPTED PURSUANT TO
               SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


      In connection with the Quarterly Report of Southwest Oil & Gas Income
Fund  VIII-A,  Limited Partnership (the "Company") on  Form  10-Q  for  the
period  ending September 30, 2003 as filed with the Securities and Exchange
Commission  on the date hereof (the "Report"), I, H.H. Wommack, III,  Chief
Executive Officer of the Managing General Partner of the Company,  certify,
pursuant  to 18 U.S.C.  1350, as adopted pursuant to  906 of the  Sarbanes-
Oxley Act of 2002, that:

  (1)   The Report fully complies with the requirements of section 13(a) or
     15(d) of the Securities Exchange Act of 1934; and

  (2)   The  information  contained in the Report fairly presents,  in  all
     material respects, the financial condition and results of operation of the
     Company.


Date:  November 14, 2003





H. H. Wommack, III
Chairman, President, Director and Chief Executive Officer
  of Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Oil & Gas Income Fund VIII-A, L.P.

<PAGE>

                          CERTIFICATION PURSUANT TO
                               Exhibit 32.2
                          19 U.S.C. SECTION 1350,
                          AS ADOPTED PURSUANT TO
               SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002


      In connection with the Quarterly Report of Southwest Oil & Gas Income
Fund  VIII-A,  Limited Partnership (the "Company") on  Form  10-Q  for  the
period  ending September 30, 2003 as filed with the Securities and Exchange
Commission  on  the date hereof (the "Report"), I, Bill  E.  Coggin,  Chief
Financial Officer of the Managing General Partner of the Company,  certify,
pursuant  to 18 U.S.C.  1350, as adopted pursuant to  906 of the  Sarbanes-
Oxley Act of 2002, that:

  (1)   The Report fully complies with the requirements of section 13(a) or
     15(d) of the Securities Exchange Act of 1934; and

  (2)   The  information  contained in the Report fairly presents,  in  all
     material respects, the financial condition and results of operation of the
     Company.


Date:  November 14, 2003





Bill E. Coggin
Executive Vice President
  and Chief Financial Officer of
  Southwest Royalties, Inc., the
  Managing General Partner of
  Southwest Oil & Gas Income Fund VIII-A, L.P.

<PAGE>