Page 3 of 18
                                 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, 1999

                                    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)

                      ________(915) 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 _____

         The total number of pages contained in this report is 18.

<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 note thereto  for
the  year ended December 31, 1998 which are found in the Registrant's  Form
10-K  Report  for  1998 filed with the Securities and Exchange  Commission.
The December 31, 1998 balance sheet included herein has been taken from the
Registrant's  1998 Form 10-K Report.  Operating results for the  three  and
nine  month periods ended September 30, 1999 are not necessarily indicative
of the results that may be expected for the full year.

<PAGE>

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

                              Balance Sheets

                                              September 30,   December 31,
                                                   1999           1998
                                              -------------   ------------
                                               (unaudited)
Assets

Current assets
 Cash and cash equivalents                     $   27,789         21,234
 Receivable from Managing General Partner         110,968         24,555
                                                ---------      ---------
     Total current assets                         138,757         45,789
                                                ---------      ---------
Oil and gas properties - using the
 full cost method of accounting                 5,344,631      5,365,357
  Less accumulated depreciation,
   depletion and amortization                   5,001,466      4,984,466
                                                ---------      ---------
     Net oil and gas properties                   343,165        380,891
                                                ---------      ---------
                                               $  481,922        426,680
                                                =========      =========

Liabilities and Partners' Equity

Current liability - Distribution payable       $      246            189
                                                ---------      ---------

Partners' equity
 General partners                                   4,869        (6,229)
 Limited partners                                 476,807        432,720
                                                ---------      ---------
     Total partners' equity                       481,676        426,491
                                                ---------      ---------
                                               $  481,922        426,680
                                                =========      =========
<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,
                                  1999      1998        1999      1998
                                  ----      ----        ----      ----
Revenues

Oil and gas                  $   260,583   210,036     626,043   707,947
Interest                             329        68         705     1,296
                               --------- ---------   --------- ---------
                                 260,912   210,104     626,748   709,243
                               --------- ---------   --------- ---------
Expenses

Production                       142,454   207,357     396,660   611,070
General and administrative        24,634    29,675      79,102    93,029
Depreciation, depletion and
 amortization                      1,000     4,500      17,000   125,500
Provision for impairment of oil
 and gas properties                    -         -           -    36,556
                               --------- ---------   --------- ---------
                                 168,088   241,532     492,762   866,155
                               --------- ---------   --------- ---------
Net income (loss)            $    92,824  (31,428)     133,986 (156,912)
                               ========= =========   ========= =========


Net income (loss) allocated to:

 Managing General Partner    $     8,445   (2,424)      13,589       463
                               ========= =========   ========= =========
 General Partner             $       938     (269)       1,510        51
                               ========= =========   ========= =========
 Limited Partners            $    83,441  (28,735)     118,887 (157,426)
                               ========= =========   ========= =========
  Per limited partner unit   $      6.14    (2.11)        8.74   (11.58)
                               ========= =========   ========= =========

<PAGE>

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

                         Statements of Cash Flows
                                (unaudited)


                                                      Nine Months Ended
                                                        September 30,
                                                       1999       1998
                                                       ----       ----
Cash flows from operating activities

 Cash received from oil and gas sales              $  544,509    796,377
 Cash paid to suppliers                             (480,641)  (678,743)
 Interest received                                        705      1,296
                                                    ---------  ---------
  Net cash provided by operating activities            64,573    118,930
                                                    ---------  ---------
Cash flows from investing activities

 Cash received from sale of oil and gas
  property interest                                    27,748     42,686
 Additions to oil and gas properties                  (7,022)        (2)
                                                    ---------  ---------
  Net cash provided by investing activities            20,726     42,684
                                                    ---------  ---------

Cash flows used in financing activities

 Distributions to partners                           (78,744)  (155,812)
                                                    ---------  ---------
Net increase in cash and cash equivalents               6,555      5,802

 Beginning of period                                   21,234      2,669
                                                    ---------  ---------
 End of period                                     $   27,789      8,471
                                                    =========  =========

                                                             (continued)
<PAGE>

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

                    Statements of Cash Flows, continued
                                (unaudited)


                                                      Nine Months Ended
                                                        September 30,
                                                       1999       1998
                                                       ----      ----
Reconciliation of net income (loss) to net
 cash provided by operating activities

Net income (loss)                                  $  133,986  (156,912)

Adjustments to reconcile net income (loss) to
 net cash provided by operating activities

 Depreciation, depletion and amortization              17,000    125,500
 Provision for impairment of oil and gas
  properties                                                -     36,556
 (Increase) decrease in receivables                  (81,534)     88,430
 Increase (decrease) in payables                      (4,879)     25,356
                                                    ---------  ---------
Net cash provided by operating activities          $   64,573    118,930
                                                    =========  =========


<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 and H. H. Wommack,  III,
     as  the individual general partner.  Revenues, costs and expenses  are
     allocated as follows:

                                                     Limited      General
                                                     Partners     Partners
                                                     --------     --------
     Interest income on capital contributions          100%          -
     Oil and gas sales                                  90%         10%
     All other revenues                                 90%         10%
     Organization and offering costs (1)               100%          -
     Amortization of organization costs                100%          -
     Syndication costs                                 100%          -
     Property acquisition costs                        100%          -
     Gain/loss on property disposition                  90%         10%
     Operating and administrative costs (2)             90%         10%
     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, 1999,  and  for
     the  three  and  nine months ended September 30, 1999,  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 audited  financial
     statements for the year ended December 31, 1998.

<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 the  possibility  of
performing  workovers  during the last quarter of  1999.   The  Partnership
could possibly experience a normal decline of 10% to 12% 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.

The  Partnership's policy for depreciation, depletion and  amortization  of
oil  and  gas  properties is computed under the units  of  revenue  method.
Under the units of revenue method, depreciation, depletion and amortization
is  computed  on  the  basis of current gross revenues from  production  in
relation  to future gross revenues, based on current prices, from estimated
production of proved oil and gas reserves.

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.   For  the  quarter ended September  30,  1999,  the  net
capitalized cost did not exceed the estimated present value of oil and  gas
reserves.   A  return to the oil price environment experienced  during  the
first  two  quarters of 1999 would have an adverse affect on the  Company's
revenues  and  operating cash flow.  Also, further declines in  oil  prices
could result in additional decreases in the carrying value of the Company's
oil and gas properties.

<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended September 30, 1999 and 1998

The  following  table  provides certain information  regarding  performance
factors for the quarters ended September 30, 1999 and 1998:

                                                 Three Months
                                                    Ended        Percentage
                                                September 30,     Increase
                                                1999      1998   (Decrease)
                                                ----      ----   ---------

Average price per barrel of oil            $   20.67     12.10      71%
Average price per mcf of gas               $    2.20      2.02       9%
Oil production in barrels                     10,660    13,800    (23%)
Gas production in mcf                         18,300    21,300    (14%)
Gross oil and gas revenue                  $ 260,583   210,036      24%
Net oil and gas revenue                    $ 118,129     2,679   4,309%
Partnership distributions                  $  40,801     2,000   1,940%
Limited partner distributions              $  36,801     1,800   1,945%
Per unit distribution to limited partners  $    2.71       .13   1,945%
Number of limited partner units               13,596    13,596


Revenues

The  Partnership's oil and gas revenues increased to $260,583 from $210,036
for  the  quarters  ended  September 30, 1999 and  1998,  respectively,  an
increase  of  24%.  The principal factors affecting the comparison  of  the
quarters ended September 30, 1999 and 1998 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the quarter ended September 30, 1999 as  compared  to
    the  quarter  ended  September 30, 1998 by 71%, or  $8.57  per  barrel,
    resulting  in  an increase of approximately $118,270 in revenues.   Oil
    sales  represented  85% of total oil and gas sales during  the  quarter
    ended  September 30, 1999 as compared to 80% during the  quarter  ended
    September 30, 1998.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 9%, or $.18 per mcf, resulting  in
    an increase of approximately $3,800 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $122,070.   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 3,100 barrels or 23% during the
     quarter  ended  September 30, 1999 as compared to  the  quarter  ended
     September  30, 1998, resulting in a decrease of approximately  $64,900
     in revenues.

    Gas production decreased approximately 3,000 mcf or 14% during the same
    period, resulting in a decrease of approximately $6,600 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $71,500.  The decrease in production is primarily due  to
    property sales and the shut-in of wells, which were deemed uneconomical
    to  operate  during  the  low prices experienced  throughout  the  last
    eighteen months.

Costs and Expenses

Total  costs  and  expenses decreased to $168,088  from  $241,532  for  the
quarters  ended September 30, 1999 and 1998, respectively,  a  decrease  of
30%.   The  decrease  is  the  result of lower lease  operating  costs  and
depletion expense and general and administrative expense.

1.    Lease  operating  costs  and production  taxes  were  31%  lower,  or
   approximately $64,900 less during the quarter ended September 30, 1999 as
   compared to the quarter ended September 30, 1998.  The decline in  lease
   operating  costs  is  primarily in relation to the drop  in  oil  prices
   experienced throughout 1998 and into the first six months of 1999, which
   made  it  uneconomical to perform workovers and major repairs.  Although
   prices  have  increased during the third quarter of 1999,  only  routine
   repairs and maintenance for the most part are being performed.

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  decreased
    17% or approximately $5,000 during the quarter ended September 30, 1999
    as  compared  to the quarter ended September 30, 1998. The decrease  of
    general  and  administrative  costs were  in  part  due  to  additional
    accounting costs incurred in 1998 in relation to the outsourcing of K-1
    tax  package preparation; a change in auditors requiring opinions  from
    both  the  predecessors and successor auditors  and  a  new  accounting
    pronouncement requiring review by the independent auditors of  the  10-
    Q's.   The Managing General Partner has also made an effort to cut back
    on general and administrative costs whenever and wherever possible.

3.  Depletion  expense decreased to $1,000 for the quarter ended  September
    30,  1999  from $4,500 for the same period in 1998.  This represents  a
    decrease  of 78%.  Depletion is calculated using the units  of  revenue
    method  of  amortization based on a percentage of current period  gross
    revenues  to  total future gross oil and gas revenues, as estimated  by
    the  Partnership's  independent  petroleum  consultants.   Contributing
    factors  to  the  decline in depletion expense between the  comparative
    periods were the increase in the price of oil and gas used to determine
    the Partnership's reserves for October 1, 1999 as compared to 1998.

<PAGE>

B.   General Comparison of the Nine Month Periods Ended September 30,  1999
and 1998

The  following  table  provides certain information  regarding  performance
factors for the nine month periods ended September 30, 1999 and 1998:

                                                 Nine Months
                                                    Ended        Percentage
                                                September 30,     Increase
                                                1999      1998   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil            $   15.25     13.13      16%
Average price per mcf of gas               $    2.23      2.18       2%
Oil production in barrels                     33,750    43,600    (23%)
Gas production in mcf                         49,960    62,100    (20%)
Gross oil and gas revenue                  $ 626,043   707,947    (12%)
Net oil and gas revenue                    $ 229,383    96,877     137%
Partnership distributions                  $  78,801   155,737    (49%)
Limited partner distributions              $  74,801   140,887    (47%)
Per unit distribution to limited partners  $    5.50     10.36    (47%)
Number of limited partner units               13,596    13,596

Revenues

The  Partnership's oil and gas revenues decreased to $626,043 from $707,947
for  the  nine  months ended September 30, 1999 and 1998,  respectively,  a
decrease  of  12%.  The principal factors affecting the comparison  of  the
nine months ended September 30, 1999 and 1998 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the nine months ended September 30, 1999 as  compared
    to  the  nine  months ended September 30, 1998 by  16%,  or  $2.12  per
    barrel,  resulting in an increase of approximately $92,400 in revenues.
    Oil  sales represented 82% of total oil and gas sales during  the  nine
    months  ended  September 30, 1999 as compared to 81%  during  the  nine
    months ended September 30, 1998.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 2%, or $.05 per mcf, resulting  in
    an increase of approximately $3,100 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $95,500.  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 9,850 barrels or 23% during  the
   nine  months  ended September 30, 1999 as compared to  the  nine  months
   ended  September  30,  1998,  resulting in a decrease  of  approximately
   $150,200 in revenues.

   Gas  production  decreased approximately 12,140 mcf or  20%  during  the
   same  period,  resulting  in  a  decrease of  approximately  $27,100  in
   revenues.

   The  total  decrease  in  revenues due to the change  in  production  is
   approximately $177,300.  The decrease in production is primarily due  to
   property  sales and the shut-in of wells, which were deemed uneconomical
   to  operate  during  the  low  prices experienced  throughout  the  last
   eighteen months.

Costs and Expenses

Total  costs and expenses decreased to $492,762 from $866,155 for the  nine
months ended September 30, 1999 and 1998, respectively, a decrease of  43%.
The  decrease  is  the result of lower general and administrative  expense,
depletion expense and lease operating costs.

1. Lease   operating  costs  and  production  taxes  were  35%  lower,   or
   approximately  $214,400 less during the nine months ended September  30,
   1999  as  compared  to the nine months ended September  30,  1998.   The
   decline  in lease operating costs is primarily in relation to  the  drop
   in  oil prices experienced throughout 1998 and into the first six months
   of  1999,  which  made  it uneconomical to perform workovers  and  major
   repairs.   Although prices have increased during the  third  quarter  of
   1999,  only routine repairs and maintenance for the most part are  being
   performed.

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  decreased
    15% or approximately $13,900 during the nine months ended September 30,
    1999  as  compared to the nine months ended September  30,  1998.   The
    decrease  of  general  and administrative costs were  in  part  due  to
    additional  accounting  costs incurred  in  1998  in  relation  to  the
    outsourcing  of  K-1  tax package preparation;  a  change  in  auditors
    requiring  opinions  from both the predecessors and successor  auditors
    and  a new accounting pronouncement requiring review by the independent
    auditors of the 10-Q's.  The Managing General Partner has also made  an
    effort  to  cut back on general and administrative costs  whenever  and
    wherever possible.

3.  Depletion  expense  decreased to $17,000  for  the  nine  months  ended
    September  30,  1999 from $125,500 for the same period in  1998.   This
    represents a decrease of 86%.  Depletion is calculated using the  units
    of  revenue  method  of amortization based on a percentage  of  current
    period  gross  revenues to total future gross oil and gas revenues,  as
    estimated  by  the  Partnership's  independent  petroleum  consultants.
    Contributing  factors to the decline in depletion expense  between  the
    comparative periods were the increase in the price of oil and gas  used
    to determine the Partnership's reserves for October 1, 1999 as compared
    to 1998.

4. The  net capitalized costs for the nine months ended September 30,  1998
   exceeded   the  estimated  present  value  of  oil  and  gas   reserves,
   discounted  at  10%  in the amount of $36,556, such  excess  costs  were
   charged  to current expense.  The write-down had the effect of  reducing
   net income, but did not affect cash flow or partner distributions.



<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 $64,600  in
the  nine  months  ended  September 30, 1999 as compared  to  approximately
$118,900  in the nine months ended September 30, 1998.  The primary  source
of the 1999 cash flow from operating activities was profitable operations.

Cash  flows provided by investing activities were approximately $20,700  in
the  nine  months  ended  September 30, 1999 as compared  to  approximately
$42,700 in the nine months ended September 30, 1998.  The principle  source
of  the 1999 cash flow from investing activities was the change in oil  and
gas properties.

Cash  flows used in financing activities were approximately $78,700 in  the
nine  months ended September 30, 1999 as compared to approximately $155,800
in  the  nine  months ended September 30, 1998.  The only use in  financing
activities was the distributions to partners.

Total  distributions during the nine months ended September 30,  1999  were
$78,801 of which $74,801 was distributed to the limited partners and $4,000
to  the  general  partners.  The per unit distribution to limited  partners
during  the  nine  months  ended  September  30,  1999  was  $5.50.   Total
distributions during the nine months ended September 30, 1998 were $155,737
of  which  $140,887 was distributed to the limited partners and $14,850  to
the general partners.  The per unit distribution to limited partners during
the nine months ended September 30, 1998 was $10.36.

The  sources  for  the  1999  distributions of $78,801  were  oil  and  gas
operations  of  approximately  $64,600  and  the  change  in  oil  and  gas
properties  of  approximately  $20,700,  resulting  with  excess  cash  for
contingencies  or  subsequent distributions.   The  sources  for  the  1998
distributions  of  $155,737  were oil and gas operations  of  approximately
$118,900 and the change in oil and gas properties of approximately $42,700,
resulting with excess cash for contingencies or subsequent distributions.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $7,103,421 have been made to the partners.  As of September  30,  1999,
$6,437,950 or $473.52 per limited partner unit has been distributed to  the
limited partners, representing a 95% return of the capital contributed.

As  of  September 30, 1999, the Partnership had approximately  $138,500  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual commitments and believes the revenues generated from operations
are adequate to meet the needs of the Partnership.


<PAGE>
Liquidity - Managing General Partner
The  Managing General Partner has a highly leveraged capital structure with
over  $21.0 million of interest payments due within next twelve  months  on
its  debt  obligations.   Due  to the severely depressed  commodity  prices
experienced for the past eighteen months, the Managing General  Partner  is
experiencing  difficulty in generating sufficient cash  flow  to  meet  its
obligations  and sustain its operations.  The Managing General  Partner  is
currently  in  the  process  of renegotiating  the  terms  of  its  various
obligations  with its creditors and/or attempting to seek  new  lenders  or
equity  investors.   Additionally,  the  Managing  General  Partner   would
consider disposing of certain assets in order to meet its obligations.

There  can  be  no  assurance  that  the Managing  General  Partner's  debt
restructuring efforts will be successful or that the lenders will agree  to
a   course   of  action  consistent  with  the  Managing  General  Partners
requirements  in restructuring the obligations.  Even if such agreement  is
reached,  it  may  require approval of additional  lenders,  which  is  not
assured.   Furthermore, there can be no assurance that the sales of  assets
can  be  successfully  accomplished on terms  acceptable  to  the  Managing
General   Partner.   Under  current  circumstances,  the  Managing  General
Partner's  ability to continue as a going concern depends upon its  ability
to  (1)  successfully  restructure  its obligations  or  obtain  additional
financing  as  may  be  required, (2) maintain  compliance  with  all  debt
covenants, (3) generate sufficient cash flow to meet its obligations  on  a
timely  basis, and (4) achieve satisfactory levels of future earnings.   If
the  Managing  General Partner is unsuccessful in its efforts,  it  may  be
unable to meet its obligations making it necessary to undertake such  other
actions as may be appropriate to preserve asset values.

Information Systems for the Year 2000
The  Managing  General Partner provides all data processing  needs  of  the
Partnership.  The Managing General Partner has identified and assessed  its
exposure  to the potential Year 2000 software and imbedded chip  processing
and  date  sensitivity issue.  Through the Managing General  Partners  data
processing  subsidiary,  Midland Southwest  Software,  Inc.,  the  Managing
General   Partner  proactively  initiated  an  internal  plan  to  identify
applicable hardware and software, assess impact and effect, estimate costs,
construct and implement corrective actions, and prepare contingency plans.

Identification & Assessment
The  Managing General Partner currently believes it identified the internal
and  external  software  and  hardware that  had  the  potential  for  date
sensitivity   problems.   Four  critical  systems  and/or  functions   were
identified  and addressed:  (1) the proprietary software of the Partnership
(OGAS)  that  is  used  for  oil & gas property  management  and  financial
accounting  functions, (2) the DEC VAX/VMS hardware and  operating  system,
(3)  various  third-party  application software  including  lease  economic
analysis,   fixed   asset   management,   geological   applications,    and
payroll/human resource programs, and (4) External Agents.

The   proprietary   software  of  the  Partnership   has   met   compliance
requirements.  Since this is an internally generated software package,  the
Managing  General  Partner  incurred approximately  $25,000  in  man-hours.
Modifications were made by internal staff and did not represent  additional
costs  to  the  Partnership.  The Managing General  Partner  has  not  made
contingency  plans at this time since the conversion is ahead  of  schedule
and   being  handled  by  Managing  General  Partner  controlled   internal
programmers.  Given the complexity of the systems that were modified, it is
anticipated  that  some  problems  may arise,  but  having  met  the  early
completion  date,  the Managing General Partner feels  that  adequate  time
remains available to overcome unforeseen delays.




<PAGE>
DEC has released a fully compliant version of its operating system that  is
used  by  the  Partnership on the DEC VAX system.  It  was  installed,  the
Managing  General Partner believes that this solved any potential  problems
on the system.

The  Managing  General Partner has identified various third-party  software
that may have date sensitivity problems and is continuing to work with  the
vendors  to  secure solutions as well as prepare contingency plans.   After
review  and evaluation of the vendor plans and status, the Managing General
Partner believes that the problems will be resolved prior to the year  2000
or   the  alternate  contingency  plan  will  sufficiently  and  adequately
remediate  the problem so that there is no material disruption to  business
functions.

The  External  Agents  of  the  Partnership include  suppliers,  customers,
owners,  vendors, banks, product purchasers including pipelines, and  other
oil  and  gas property operators.  The Managing General Partner is  in  the
process of identifying and communicating with each critical External  Agent
about  its  plan  and progress thereof in addressing the Year  2000  issue.
This process is on schedule and the Managing General Partner, at this time,
believes  that  there  should  be no material  interference  or  disruption
associated with any of the critical External Agent's functions necessary to
the   Partnership's  business.   The  Managing  General  Partner  estimates
completion of this audit by year end 1999 and believes that alternate plans
can  be  devised to circumvent any material problems arising from  critical
External Agent noncompliance.

Cost
To  date,  the Managing General Partner has incurred only minimal  internal
man-hour costs for identification, planning, and maintenance.  The Managing
General  Partner believes that the necessary additional costs will also  be
minimal  and most will fall under normal and general maintenance procedures
and updates.  An accurate cost cannot be determined at this time, but it is
expected  that  the total cost to remediate all systems  to  be  less  than
$50,000.

Risks/Contingency
The  failure to correct critical systems of the Partnership, or the failure
of  a  material business partner or External Agent to resolve critical Year
2000  issues  could  have a serious adverse impact on the  ability  of  the
Partnership  to  continue operations and meet obligations.   Based  on  the
Managing  General  Partner's  evaluation and  assessment  to  date,  it  is
believed  that any interruption in operation will be minor and  short-lived
and  pose no material monetary loss, safety, or environmental risk  to  the
Partnership.   However,  due  to  the  external  nature  of  the  potential
problems,  it  is  impossible to accurately identify  the  risks,  quantify
potential  impacts  or  establish a final contingency  plan.  The  Managing
General Partner believes that its assessment and contingency planning  will
be complete no later than year-end 1999.

<PAGE>
Worst Case Scenario
The  Securities  and  Exchange  Commission  requires  public  companies  to
forecast the most reasonably likely worst case Year 2000 scenario, assuming
that  the  Managing  General Partner's Year 2000  plan  is  not  effective.
Analysis  of the most reasonably likely worst case Year 2000 scenarios  the
Partnership  may face leads to contemplation of the following possibilities
which,  though  considered  highly  unlikely,  must  be  included  in   any
consideration  of worst cases: widespread failure of electrical,  gas,  and
similar   supplies   by  utilities  serving  the  Partnership;   widespread
disruption  of  the  services of communications  common  carriers;  similar
disruption to means and modes of transportation for the Partnership and its
employees, contractors, suppliers, and customers; significant disruption to
the  Partnership's  ability to gain access to,  and  continue  working  in,
office  buildings  and other facilities; and the failure, of  third-parties
systems,  the  effects  of which would have a cumulative  material  adverse
impact  on  the  Partnership's  critical systems.   The  Partnership  could
experience  an inability by customers, traders, and others  to  pay,  on  a
timely  basis or at all, obligations owed to the Partnership.  Under  these
circumstances, the adverse effect on the Partnership, and the diminution of
Partnership revenues, could be material, although not quantifiable at  this
time.

<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:

             27 Financial Data Schedule

             (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, Vice President
                                        and Chief Financial Officer

Date:     November 15, 1999

<PAGE>