1 of 26

                                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 June 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 & 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      No  X

Indicate  by check mark whether the 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
annual 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  six  month  periods ended June 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  June 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 June  30,
2002.

<PAGE>
               Southwest Oil & Gas Income Fund VIII-A, L.P.
                              Balance Sheets

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

Current assets:
 Cash and cash equivalents    $  231,866   56,709
  Receivable  from  Managing     134,936   133,263
General Partner
                                 --------  --------
                                 ----      ----
   Total current assets          366,802   189,972
                                 --------  --------
                                 ----      ----

Oil  and  gas  properties  -
using the full-
 cost method of accounting       5,345,71  5,438,77
                                 9         9
       Less      accumulated
depreciation,
         depletion       and     5,050,21  5,107,46
amortization                     8         6
                                 --------  --------
                                 ----      ----
      Net   oil   and    gas     295,501   331,313
properties
                                 --------  --------
                                 ----      ----
                              $  662,303   521,285
                                 =======   =======

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

Current     liability      -  $  159       199
distribution payable
                                 --------  --------
                                 ----      ----
Other long term liabilities      244,273   -
                                 --------  --------
                                 ----      ----
Partners' equity -
 General partner                 10,289    19,410
 Limited partners                407,582   501,676
                                 --------  --------
                                 ----      ----
   Total partners' equity        417,871   521,086
                                 --------  --------
                                 ----      ----
                              $  662,303   521,285
                                 =======   =======

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

                                   Three Months Ended   Six Months Ended
                                        June 30,            June 30,
                                     2003      2002      2003      2002
                                             (Restate            (Restate
                                                d)                  d)
                                    -----     -----     -----     -----
Revenues
-------------
Oil and gas                     $  320,809   238,634   749,377   455,978
Interest                           472       70        628       217
Miscellaneous settlement           45        309       46        309
                                   --------  --------  --------  --------
                                   --        --        --        --
                                   321,326   239,013   750,051   456,504
                                   --------  --------  --------  --------
                                   --        --        --        --
Expenses
-------------
Production                         166,358   158,610   335,923   304,469
General and administrative         33,949    25,528    60,065    51,623
Depreciation,  depletion   and     3,000     7,000     12,000    14,000
amortization
Accretion  of asset retirement     4,698     -         11,702    -
obligation
                                   --------  --------  --------  --------
                                   --        --        --        --
                                   208,005   191,138   419,690   370,092
                                   --------  --------  --------  --------
                                   --        --        --        --
Net   income  from  continuing     113,321   47,875    330,361   86,412
operations

Results    from   discontinued
operations-
  sale of oil and gas leases -     12,153    6,097     20,343    11,468
See Note 5
                                   --------  --------  --------  --------
                                   --        --        --        --
Net  income  before cumulative     125,474   53,972    350,704   97,880
effect

Cumulative effect of change in
accounting
  principle - SFAS No.  143  -     -         -         (158,919  -
See Note 3                                             )
Cumulative effect of change in
accounting principle
  - change in depletion method     -         -         -         (5,000)
- See Note 4
                                   --------  --------  --------  --------
                                   --        --        --        --
Net income                      $  125,474   53,972    191,785   92,880
                                   ======    ======    ======    ======


continued
<PAGE>
               Southwest Oil & Gas Income Fund VIII-A, L.P.
                         Statements of Operations
                               (unaudited)

                                   Three Months Ended   Six Months Ended
                                        June 30,            June 30,
                                     2003      2002      2003      2002
                                             (Restate            (Restate
                                                d)                  d)
                                    -----     -----     -----     -----
Net income allocated to:
 Managing General Partner       $  12,847    5,487     20,379    10,069
                                   ======    ======    ======    ======
 General Partner                $  -         610       -         1,119
                                   ======    ======    ======    ======
 Limited partners               $  112,627   47,875    171,407   81,692
                                   ======    ======    ======    ======
   Per  limited  partner  unit
before discontinued
    operations and  cumulative  $     7.48             21.78     5.62
effect                                       3.12
   Discontinued operations per     .80       .40       1.35      .76
limited partner unit
    Cumulative   effects   per     -         -         (10.52)   (.37)
limited partner unit
                                   --------  --------  --------  --------
                                   --        --        --        --
  Per limited partner unit      $     8.28             12.61     6.01
                                             3.52
                                   ======    ======    ======    ======
Pro   forma  amounts  assuming
changes are applied
 retroactively (See Note 3):
  Net income before cumulative  $  -         47,527    -         84,992
effect
                                   ======    ======    ======    ======
   Per  limited  partner  unit  $  -            3.10   -            5.53
(13,596.0)
                                   ======    ======    ======    ======
 Net income                     $  -         47,527    -         79,992
                                   ======    ======    ======    ======
   Per  limited  partner  unit  $        -             -            5.16
(13,596.0)                                   3.10
                                   ======    ======    ======    ======

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

                                            Six Months Ended
                                                June 30,
                                             2003      2002
                                                     (Restate
                                                        d)
                                            -----     -----
Cash flows from operating activities:
 Cash received from oil and gas sales   $  732,592   421,459
 Cash paid to suppliers                    (380,877  (363,116
                                           )         )
   Cash   received  from  discontinued     20,343    11,468
operations
 Interest received                         628       217
 Miscellaneous settlement                  46        309
                                           --------  --------
                                           --        ---
    Net  cash  provided  by  operating     372,732   70,337
activities
                                           --------  --------
                                           --        ---
Cash flows from investing activities:
 Sale of oil and gas properties            107,187   -
 Additions to oil and gas properties       (9,722)   (34,220)
                                           --------  --------
                                           --        ---
   Net  cash  provided  by  (used  in)     97,465    (34,220)
investing activities
                                           --------  --------
                                           --        ---
Cash    flows   used   in    financing
activities:
 Distributions to partners                 (295,040  (32,094)
                                           )
                                           --------  --------
                                           --        ---
Net   increase   in  cash   and   cash     175,157   4,023
equivalents

Beginning of period                        56,709    37,385
                                           --------  --------
                                           --        ---
End of period                           $  231,866   41,408
                                           ======    ======
Reconciliation of net income to net
    cash    provided   by    operating
activities:

Net income                              $  191,785   92,880

Adjustments to reconcile net income to
   net   cash  provided  by  operating
activities:
     Depreciation,    depletion    and     12,000    14,000
amortization
   Accretion   of   asset   retirement     11,702    -
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 in receivables                   (16,785)  (34,519)
 Increase (decrease) in payables           15,111    (7,024)
                                           --------  --------
                                           --        ---
Net   cash   provided   by   operating  $  372,732   70,337
activities
                                           ======    ======
Noncash    investing   and   financing
activities:
  Increase in oil and gas properties -
Adoption
  of SFAS No. 143                       $  191,308   -
                                           ======    ======
  Decrease in oil and gas 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 June 30, 2003, and  for  the
     three  and  six  months  ended June 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 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 June  30,
     2003,  the  asset retirement obligation was $244,273. The decrease  in
     the  balance from January 1, 2003 is due to the sale of an oil and gas
     property, which decreased the asset retirement obligation by  $117,656
     offset  slightly  by  accretion expense of  $11,702.   The  pro  forma
     amounts  for the three and six months ended June 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 six months ended  June  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 June 30, 2002.  The effect of the change on the six
     months  ended  June 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
     $106,240  sales  proceeds  and retired $117,655  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       Six Months Ended
                                   2003       2002         2003       2002

         Revenues                $20,247    16,841       34,987    30,897
         Net income              12,153     6,097        20,343    11,468


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

                      Notes to Financial Statements

6.   June 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 six months ended June 30, 2002.

                                  Three Months Ended       Six Months Ended
                                         (1)
                                            Previous               Previously
                                               ly
                                            Reported     Restated   Reported
         Depreciation,
         depletion and
          Amortization                      $7,000       14,000    13,000
         Income before                      53,972       97,880    98,880
         cumulative effect
       Cumulative effect of
         change in
          accounting principle              -            (5,000)   -
         Net income                         53,972       92,880    98,880
         Net income allocated
         to:
         Managing General                   5,487        10,069    10,069
         Partner
         General partner                    610          1,119     1,119
         Limited partners                   47,875       81,692    87,692
          Income per limited
         partner
            unit before                                                6.45
         cumulative effect                  3.52         6.38
          Cumulative effect
         per limited
            partner unit                         -                     -
                                                         (.37)
          Net income per
         limited
            partner unit                                               6.45
                                            3.52         6.01

(1) There was  no  effect  due  to the change in depletion  method  on  the
          quarter ended June 30, 2002.

<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 June 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 June 30, 2003 and 2002

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

                               Three Months
                                  Ended         Percenta
                                                   ge
                                 June 30,       Increase
                              2003      2002    (Decreas
                                                   e)
                              ----      ----    --------
                                                   --
Average    price    per  $   28.00              17%
barrel of oil                         23.94
Average  price per  mcf  $    4.66              43%
of gas                                3.25
Oil    production    in     10,100    9,000     12%
barrels
Gas production in mcf       12,500    12,300    2%
Gross   oil   and   gas  $  341,056   255,475   33%
revenue
Net oil and gas revenue  $  166,604   86,121    93%
Partnership              $  200,000   -         100%
distributions
Limited         partner  $  180,000   -         100%
distributions
Per  unit  distribution
to limited
 partners                $   13.24         -    100%
Number    of    limited     13,596    13,596
partner units

Revenues

The  Partnership's oil and gas revenues increased to $341,056 from $255,475
for the quarters ended June 30, 2003 and 2002, respectively, an increase of
33%.   The principal factors affecting the comparison of the quarters ended
June 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 June 30, 2003 as  compared  to  the
    quarter  ended June 30, 2002 by 17%, or $4.06 per barrel, resulting  in
    an   increase  of  approximately  $41,000  in  revenues.    Oil   sales
    represented  83%  of total oil and gas sales during the  quarter  ended
    June  30,  2003  as compared to 84% during the quarter ended  June  30,
    2002.

    The  average  price  for  a  mcf  of gas received  by  the  Partnership
    increased during the same period by 43% or $1.41 per mcf, resulting  in
    an increase of approximately $17,600 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $58,600.  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 1,100 barrels or 12% during the
    quarter  ended June 30, 2003 as compared to the quarter ended June  30,
    2002, resulting in an increase of approximately $26,300 in revenues.

    Gas  production increased approximately 200 mcf or 2% during  the  same
    period, resulting in an increase of approximately $700 in revenues.

    The  total  increase  in revenues due to the change  in  production  is
    approximately $27,000.

Costs and Expenses

Total  costs  and  expenses increased to $216,099  from  $201,882  for  the
quarters  ended  June 30, 2003 and 2002, respectively, an increase  of  7%.
The  increase  is a direct result of the accretion expense associated  with
our  long-term liability related to expected abandonment costs of  our  oil
and  gas  properties, lease operating cost and general  and  administrative
expense, partially offset by a decrease in depletion expense.

1.  Lease  operating  costs  and  production  taxes  were  3%  higher,   or
    approximately  $5,100 more during the quarter ended June  30,  2003  as
    compared to the quarter ended June 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
    33%  or approximately $8,400 during the quarter ended June 30, 2003  as
    compared  to the quarter ended June 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 $3,000 for the quarter ended  June  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
    June  30,  2002. The contributing factor to the decrease  in  depletion
    expense is in relation to the BOE depletion rate for the quarter  ended
    June 30, 2003, which was $.25 applied to 12,183 BOE as compared to $.63
    applied  to 11,050 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 Six Month Periods Ended June  30,  2003  and
    2002

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

                                     Six Months
                                       Ended         Percenta
                                                        ge
                                      June 30,       Increase
                                   2003      2002    (Decreas
                                                        e)
                                   ----      ----    --------
                                                        --
Average price per barrel  of  $    29.91             37%
oil                                        21.79
Average price per mcf of gas  $     5.40             91%
                                           2.82
Oil production in barrels        21,800    19,300    13%
Gas production in mcf            24,500    23,500    4%
Gross oil and gas revenue     $  784,364   486,875   61%
Net oil and gas revenue       $  433,797   162,977   166%
Partnership distributions     $  295,000   32,000    822%
Limited              partner  $  265,500   28,800    822%
distributions
Per  unit  distribution   to
limited
 Partners                     $    19.53             822%
                                           2.12
Number  of  limited  partner     13,596    13,596
units

Revenues

The  Partnership's oil and gas revenues increased to $784,364 from $486,875
for  the six months ended June 30, 2003 and 2002, respectively, an increase
of  61%.  The principal factors affecting the comparison of the six  months
ended June 30, 2003 and 2002 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased during the six months ended June 30, 2003 as compared to  the
    six  months ended June 30, 2002 by 37%, or $8.12 per barrel,  resulting
    in  an  increase  of  approximately $177,000  in  revenues.  Oil  sales
    represented 83% of total oil and gas sales during the six months  ended
    June  30, 2003 as compared to 86% during the six months ended June  30,
    2002.

    The  average  price  for  a  mcf  of gas received  by  the  Partnership
    increased during the same period by 91%, or $2.58 per mcf, resulting in
    an increase of approximately $63,200 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $240,200.   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 2,500 barrels or 13% during the
    six months ended June 30, 2003 as compared to the six months ended June
    30,  2002,  resulting  in  an  increase  of  approximately  $54,500  in
    revenues.

    Gas  production increased approximately 1,000 mcf or 4% during the same
    period, resulting in an increase of approximately $2,800 in revenues.

    The  total  increase  in revenues due to the change  in  production  is
    approximately $57,300.

Costs and Expenses

Total  costs and expenses increased to $434,334 from $389,521 for  the  six
months ended June 30, 2003 and 2002, respectively, an increase of 12%.  The
increase  is a direct result of the accretion expense associated  with  our
long-term  liability related to expected abandonment costs of our  oil  and
gas  properties,  lease  operating  cost  and  general  and  administrative
expense, partially offset by a decrease in depletion expense.

1.  Lease  operating  costs  and  production  taxes  were  8%  higher,   or
    approximately $26,700 more during the six months ended June 30, 2003 as
    compared to the six months ended June 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
    16%  or approximately $8,400 during the six months ended June 30,  2003
    as  compared  to  the six months ended June 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 $12,000 for the six months  ended  June
    30,  2003 from $14,000 for the same period in 2002.  This represents  a
    decrease  of  14%.   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 six
    months  ended June 30, 2002 by $1,000 and decrease net income  for  the
    six  months ended June 30, 2002 by $6,000.  The contributing factor  to
    the  decrease in depletion expense is in relation to the BOE  depletion
    rate for the six months ended June 30, 2003, which was $.46 applied  to
    25,883  BOE  as  compared to $.60 applied to 23,217 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  June  30,  2003,  the  asset
retirement  obligation  was  $244,273. The decrease  in  the  balance  from
January  1,  2003  is  due to the sale of an oil and  gas  property,  which
decreased  the asset retirement obligation by $117,656 offset  slightly  by
accretion expense of $11,702.  The pro forma amounts for the three and  six
months  ended  June  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 $372,700  in
the six months ended June 30, 2003 as compared to approximately $70,300  in
the  six  months ended June 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
$97,500  in the six months ended June 30, 2003 as compared to approximately
$(34,200)  in the six months ended June 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 $295,000 in  the
six  months ended June 30, 2003 as compared to approximately $32,100 in the
six  months  ended June 30, 2002. The only use in financing activities  was
the distributions to partners.

Total distributions during the six months ended June 30, 2003 were $295,000
of  which  $265,500 was distributed to the limited partners and $29,500  to
the  general partner.  The per unit distribution to limited partners during
the  six months ended June 30, 2003 was $19.53. Total distributions  during
the  six  months  ended  June 30, 2002 were $32,000 of  which  $28,800  was
distributed to the limited partners and $3,200 to the general partners. The
per  unit distribution to limited partners during the six months ended June
30, 2002 was $2.12.

The  sources  for  the  2003 distributions of $295,000  were  oil  and  gas
operations  of  approximately $372,700 and the net change in  oil  and  gas
properties  of  approximately  $97,500,  resulting  in  excess   cash   for
contingencies  or  subsequent  distributions.  The  sources  for  the  2002
distributions  of  $32,000  were oil and gas  operations  of  approximately
$70,300  and  the  change  in  oil  and  gas  properties  of  approximately
$(34,200),  resulting  in  excess  cash  for  contingencies  or  subsequent
distributions.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $8,585,924  have  been made to the partners.   As  of  June  30,  2003,
$8,037,703 or $591.18 per limited partner unit has been distributed to  the
limited partners, representing a 100% return of the capital and 18%  return
on capital contributed.

As  of June 30, 2003, the Partnership had approximately $366,600 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.

<PAGE>
Liquidity - Managing General Partner
The  Managing General Partner has a highly leveraged capital structure with
approximately $124.0 million of principal due between December 31, 2002 and
December  31, 2004.  The Managing General Partner is constantly  monitoring
its cash position and its ability to meet its financial obligations as they
become due, and in this effort, is continually exploring various strategies
for  addressing  its  current  and future liquidity  needs.   The  Managing
General Partner regularly pursues and evaluates recapitalization strategies
and  acquisition  opportunities  (including  opportunities  to  engage   in
mergers,  consolidations or other business combinations) and at  any  given
time may be in various stages of evaluating such opportunities.

Based   on  current  production,  commodity  prices  and  cash  flow   from
operations,  the Managing General Partner has adequate cash  flow  to  fund
debt  service, developmental projects and day to day operations, but it  is
not  sufficient  to  build a cash balance which would  allow  the  Managing
General  Partner to meet its debt principal maturities scheduled for  2004.
Therefore  the Managing General Partner is currently seeking to renegotiate
the  terms  of its obligations, including extending maturity dates,  or  to
engage  new  lenders or equity investors in order to satisfy its  financial
obligations maturing in 2004.

There  can  be  no  assurance  that  the Managing  General  Partner's  debt
restructuring efforts will be successful.  In the event these  efforts  are
unsuccessful,  the Managing General Partner would need  to  look  to  other
alternatives  to  meet its debt obligations, including potentially  selling
its  assets.  There can be no assurance, however, that the sales of  assets
can  be  successfully  accomplished on terms  acceptable  to  the  Managing
General Partner.

The  liquidity of the Managing General Partner, however, does  not  have  a
material  impact  on  the operations of the Partnership.   The  partnership
agreement  of  the  Partnership allows the  limited  partners  to  elect  a
successor managing general partner to continue Partnership operations.

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 chief executive
officer  and chief financial officer of the Partnership's Managing  General
Partner have evaluated the effectiveness of the design and operation of the
Partnership's  disclosure controls and procedures (as defined  in  Exchange
Act  Rule 13a-14(c)) as of a date within 90 days of the filing date of this
quarterly report. Based on that evaluation, the chief executive officer and
chief  financial  officer have concluded that the Partnership's  disclosure
controls  and procedures are effective to ensure that material  information
relating to the Partnership and the Partnership's consolidated subsidiaries
is   made   known  to  such  officers  by  others  within  these  entities,
particularly during the period this quarterly report was prepared, in order
to allow timely decisions regarding required disclosure.

(b)  Changes  in  Internal Controls.  There have not been  any  significant
changes  in  the Partnership's internal controls or in other  factors  that
could  significantly affect these controls subsequent to the date of  their
evaluation.


<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)                Reports on Form 8-K:

          No reports on Form 8-
             K were filed during the quarter ended June 30, 2003.

<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 & 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, Vice President
                                       and Chief Financial Officer

Date: November 12, 2003

<PAGE>
                CERTIFICATIONS                Exhibit 31.1

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

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

          2.   Based on my knowledge, this quarterly 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 quarterly report;

          3.   Based on my knowledge, the financial statements,
and other financial
information  included  in  this quarterly 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
quarterly report;

          4.   The registrant's other certifying officers and I are
 responsible for
establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

          a)   designed such disclosure controls and procedures 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 quarterly report is being
          prepared;

          b)   evaluated the effectiveness of the registrant's
disclosure controls
          and procedures as of a date within 90 days prior
to the filing date of this
          quarterly report (the "Evaluation Date"); and

          c)   presented in this quarterly report our conclusions about the
          effectiveness of the disclosure controls and procedures based on our
          evaluation as of the Evaluation Date;

          5.   The registrant's other certifying officers and I have
 disclosed, based
on  our most recent evaluation, 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 in the design or operation
of internal
          controls which could adversely affect the registrant's
 ability to record,
          process, summarize and report financial data and have
identified for the
          registrant's auditors any material weaknesses in
internal controls; 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; and

          6.   The registrant's other certifying officers and I
have indicated in
this  quarterly  report  whether or not there were significant  changes  in
internal  controls  or  in  other factors that could  significantly  affect
internal  controls  subsequent to the date of our most  recent  evaluation,
including  any  corrective actions with regard to significant  deficiencies
and material weaknesses.

Date:  November 12, 2003




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

<PAGE>
                CERTIFICATIONS                     Exhibit
                                   31.2

          I, Bill E. Coggin, certify that:

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

          2.   Based on my knowledge, this quarterly 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 quarterly report;

          3.   Based on my knowledge, the financial statements,
and other financial
     information included in this quarterly 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
     quarterly report;

          4.   The registrant's other certifying officers and I are
 responsible for
     establishing and maintaining disclosure controls and procedures (as defined
     in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

          a)   designed such disclosure controls and procedures 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 quarterly report is being
          prepared;

          b)   evaluated the effectiveness of the registrant's
 disclosure controls
          and procedures as of a date within 90 days prior
to the filing date of this
          quarterly report (the "Evaluation Date"); and

          c)   presented in this quarterly report our conclusions about the
          effectiveness of the disclosure controls and procedures based on our
          evaluation as of the Evaluation Date;

          5.   The registrant's other certifying officers and I have
disclosed, based
     on our most recent evaluation, 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 in the design or operation
 of internal
          controls which could adversely affect the registrant's
ability to record,
          process, summarize and report financial data and have
 identified for the
          registrant's auditors any material weaknesses in internal
 controls; 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; and

          6.   The registrant's other certifying officers and I have
 indicated in
     this quarterly report whether or not there were significant changes in
     internal controls or in other factors that could significantly  affect
     internal controls subsequent to the date of our most recent evaluation,
     including any corrective actions with regard to significant deficiencies
     and material weaknesses.

Date:  November 12, 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>
                         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  June  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 12, 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  June  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 12, 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>