Page 19 of 19
                                 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 33-47667-01

                SOUTHWEST OIL & GAS 1992-93 INCOME PROGRAM
               Southwest Oil and Gas Income Fund XI-A, L.P.
                  (Exact name of registrant as specified
                   in its limited partnership agreement)

Delaware                                          75-2427267
(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 19.

<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 XI-A, L.P.

                              Balance Sheets

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

Current assets
 Cash and cash equivalents                     $   13,097         34,874
 Receivable from Managing General Partner          24,842         27,378
                                                ---------      ---------
     Total current assets                          37,939         62,252
                                                ---------      ---------
Oil and gas properties - using the
 full cost method of accounting                 1,017,632      1,017,398
  Less accumulated depreciation,
   depletion and amortization                     742,555        720,555
                                                ---------      ---------
     Net oil and gas properties                   275,077        296,843
                                                ---------      ---------
                                               $  313,016        359,095
                                                =========      =========

Liabilities and Partners' Equity

Partners' equity
 General partners                              $  (7,859)        (7,892)
 Limited partners                                 320,875        366,987
                                                ---------      ---------
     Total partners' equity                       313,016        359,095
                                                ---------      ---------
                                               $  313,016        359,095
                                                =========      =========

<PAGE>

               Southwest Oil and Gas Income Fund XI-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                  $    63,793    65,180     147,972   192,696
Interest                             209       120         743       502
                                 -------   -------     -------   -------
                                  64,002    65,300     148,715   193,198
                                 -------   -------     -------   -------
Expenses

Production                        28,783    39,058      82,470   126,122
General and administrative         3,604     8,629      15,917    33,228
Depreciation, depletion and
 amortization                      5,000    12,000      22,000    61,044
Provision for impairment of
 oil and gas properties                -         -           -    59,663
                                 -------   -------     -------   -------
                                  37,387    59,687     120,387   280,057
                                 -------   -------     -------   -------
Net income (loss)            $    26,615     5,613      28,328  (86,859)
                                 =======   =======     =======   =======

Net income (loss) allocated to:

 Managing General Partner    $     2,845     1,585       4,530     3,046
                                 =======   =======     =======   =======
 General Partner             $       316       176         503       339
                                 =======   =======     =======   =======
 Limited Partners            $    23,454     3,852      23,295  (90,244)
                                 =======   =======     =======   =======
  Per limited partner unit   $      8.31      1.37        8.26    (31.99)
                                 =======   =======     =======   =======

<PAGE>

               Southwest Oil and Gas Income Fund XI-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              $  129,005    214,704
 Cash paid to suppliers                              (76,884)  (147,139)
 Interest received                                        743        502
                                                      -------    -------
  Net cash provided by operating activities            52,864     68,067
                                                      -------    -------
Cash flows from investing activities

 Additions of oil and gas properties                    (234)    (7,174)
 Sale of oil and gas properties                             -      3,993
                                                      -------    -------
  Net cash used in investing activities                 (234)    (3,181)
                                                      -------    -------
Cash flows used in financing activities

 Distributions to partners                           (74,407)   (57,785)
                                                      -------    -------
Net (decrease) increase in cash and cash equivalents            (21,777)
7,101

 Beginning of period                                   34,874      4,368
                                                      -------    -------
 End of period                                     $   13,097     11,469
                                                      =======    =======

                                                             (continued)
<PAGE>

               Southwest Oil and Gas Income Fund XI-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)                                  $   28,328   (86,859)

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

 Depreciation, depletion and amortization              22,000     61,044
 Provision for impairment of oil and gas properties                    -
59,663
 (Increase) decrease in receivables                  (18,967)     22,008
 Increase in payables                                  21,503     12,211
                                                      -------    -------
Net cash provided by operating activities          $   52,864     68,067
                                                      =======    =======


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

                      Notes to Financial Statements

1.   Organization
     Southwest  Oil  & Gas Income Fund XI-A, L.P. was organized  under  the
     laws  of  the  state of Delaware on May 5, 1992, 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 will sell  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.  Partnership profits and  losses,  as
     well as all items of income, gain, loss, deduction, or credit, will be
     credited or charged as follows:

                                                 Limited      General
                                                 Partners     Partners (1)
                                                 --------     --------
     Organization and offering expenses (2)     100%             -
     Acquisition costs                          100%             -
     Operating costs                             90%           10%
     Administrative costs (3)                    90%           10%
     Direct costs                                90%           10%
     All other costs                             90%           10%
     Interest income earned on capital
      contributions                             100%             -
     Oil and gas revenues                        90%           10%
     Other revenues                              90%           10%
     Amortization                               100%             -
     Depletion allowances                       100%             -

          (1)   H.H.  Wommack,  III,  President  of  the  Managing  General
          Partner, is an additional general partner in the Partnership  and
          has  a  one percent interest in the Partnership.  Mr. Wommack  is
          the  majority  stockholder of the Managing General Partner  whose
          continued  involvement in Partnership management is important  to
          its  operations.  Mr. Wommack, as a general partner, shares  also
          in Partnership liabilities.
          (2)   Organization and Offering Expenses (including all  cost  of
          selling  and  organizing the offering) include a payment  by  the
          Partnership of an amount equal to three percent (3%)  of  Capital
          Contributions   for   reimbursement  of   such   expenses.    All
          Organization Costs (which excludes sales commissions and fees) in
          excess  of  three  percent  (3%) of  Capital  Contributions  with
          respect to the Partnership will be allocated to and paid  by  the
          Managing General Partner.
          (3)   Administrative  Costs will be paid from  the  Partnership's
          revenues;  however; Administrative Costs in the Partnership  year
          in  excess of two percent (2%) of Capital Contributions shall  be
          allocated to and paid by the Managing General Partner.


<PAGE>
               Southwest Oil and Gas Income Fund XI-A, L.P.

                       Note to Financial Statements

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 XI-A, L.P. was organized  as  a  Delaware
limited  partnership  on  May  5,  1992.   The  offering  of  such  limited
partnership  interests began August 20, 1992 as part of  a  shelf  offering
registered  under  the  name Southwest Oil & Gas  1992-93  Income  Program.
Minimum  capital  requirements for the Partnership were met  on  March  17,
1993,  with the offering of limited partnership interests concluding  April
30,  1993.   At  the  conclusion  of the offering  of  limited  partnership
interests, 122 limited partners had purchased 2,821 units for $1,410,500.

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 will not be 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,  lease
operating  expenses, enhanced recovery projects, offset drilling activities
pursuant to farmout 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 next year.  The Partnership could  possibly
experience a steady decline.

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 nine months ended September 30,  1999,  the  net
capitalized costs did not exceed the estimated present value.  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            $   20.11     12.04     67%
Average price per mcf of gas               $    2.52      2.10     20%
Oil production in barrels                      1,410     1,900   (26%)
Gas production in mcf                         14,080    18,900   (26%)
Gross oil and gas revenue                  $  63,793    65,180    (2%)
Net oil and gas revenue                    $  35,010    26,122     34%
Partnership distributions                  $  20,000    11,000     82%
Limited partner distributions              $  18,000     9,900     82%
Per unit distribution to limited partners  $    6.38      3.51     82%
Number of limited partner units                2,821     2,821


Revenues

The  Partnership's oil and gas revenues decreased to $63,793  from  $65,180
for  the  quarters  ended  September 30, 1999  and  1998,  respectively,  a
decrease  of  2%.   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 67%, or  $8.07  per  barrel,
    resulting  in  an increase of approximately $15,300 in  revenues.   Oil
    sales  represented  44% of total oil and gas sales during  the  quarter
    ended  September 30, 1999 as compared to 37% 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 20%, or $.42 per mcf, resulting  in
    an increase of approximately $7,900 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $23,200.  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 decreased approximately 490 barrels or 26% during the
   quarter ended September 30, 1999 as compared to the quarter
   ended September 30, 1998, resulting in a decrease of approximately $9,900
   in revenues.

    Gas production decreased approximately 4,820 mcf or 26% during the same
    period, resulting in a decrease of approximately $12,100 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $22,000.  The decrease in production is due primarily  to
    property sales and natural decline.

Costs and Expenses

Total costs and expenses decreased to $37,387 from $59,687 for the quarters
ended  September 30, 1999 and 1998, respectively, a decrease of  37%.   The
decrease  is  the result of lower lease operating costs, depletion  expense
and general and administrative expense.

1.    Lease  operating  costs  and production  taxes  were  26%  lower,  or
   approximately $10,300 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
    58% 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 $5,000 for the quarter ended  September
    30,  1999 from $12,000 for the same period in 1998.  This represents  a
    decrease  of 58%.  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            $   14.83     12.27      21%
Average price per mcf of gas               $    2.08      2.00       4%
Oil production in barrels                      4,080     6,400    (36%)
Gas production in mcf                         42,080    55,900    (25%)
Gross oil and gas revenue                  $ 147,972   192,696    (23%)
Net oil and gas revenue                    $  65,502    66,574     (2%)
Partnership distributions                  $  74,407    57,784      29%
Limited partner distributions              $  69,407    52,084      33%
Per unit distribution to limited partners  $   24.60     18.46      33%
Number of limited partner units                2,821     2,821

Revenues

The  Partnership's oil and gas revenues decreased to $147,972 from $192,696
for  the  nine  months ended September 30, 1999 and 1998,  respectively,  a
decrease  of  23%.  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  21%,  or  $2.56  per
    barrel,  resulting in an increase of approximately $16,400 in revenues.
    Oil  sales  represented  41% of total oil  and  gas  sales  during  the
    quarters ended September 30, 1999 and 1998.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 4%, or $.08 per mcf, resulting  in
    an increase of approximately $4,500 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from oil and gas production is approximately $20,900.  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 2,320 barrels or 36% during the
    nine  months  ended September 30, 1999 as compared to the  nine  months
    ended  September  30,  1998, resulting in a decrease  of  approximately
    $34,400 in revenues.

    Gas  production  decreased approximately 13,820 mcf or 25%  during  the
    same  period,  resulting  in  a decrease of  approximately  $28,700  in
    revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $63,100.  The decrease in production is due primarily  to
    property sales in 1998.

Costs and Expenses

Total  costs and expenses decreased to $120,387 from $280,057 for the  nine
months ended September 30, 1999 and 1998, respectively, a decrease of  57%.
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  $43,700 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
    52% or approximately $17,300 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 $22,000  for  the  nine  months  ended
    September  30,  1999 from $60,000 for the same period  in  1998.   This
    represents a decrease of 63%.  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 $59,663, 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 $52,900  in
the  nine  months  ended  September 30, 1999 as compared  to  approximately
$68,100 in the nine months ended September 30, 1998.  The primary source of
the 1999 cash flow from operating activities was profitable operations.

Cash flows used in investing activities were approximately $200 in the nine
months ended September 30, 1999 as compared to approximately $3,200 in  the
nine  months ended September 30, 1998.  The principle use of the 1999  cash
flow from investing activities was the change in oil and gas properties.

Cash  flows used in financing activities were approximately $74,400 in  the
nine  months ended September 30, 1999 as compared to approximately  $57,800
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
$74,407 of which $69,407 was distributed to the limited partners and $5,000
to  the  general  partners.  The per unit distribution to limited  partners
during  the  nine  months  ended September  30,  1999  was  $24.60.   Total
distributions during the nine months ended September 30, 1998 were  $57,784
of  which $52,084 was distributed to the limited partners and $5,700 to the
general partners.  The per unit distribution to limited partners during the
nine months ended September 30, 1998 was $18.46.

The source for the 1999 distributions of $74,407 was oil and gas operations
of  approximately  $52,900, partially offset by a change  in  oil  and  gas
properties of approximately $(200), with the balance from available cash on
hand   at  the  beginning  of  the  period.   The  sources  for  the   1998
distributions  of  $57,784  were oil and gas  operations  of  approximately
$68,100,  partially  offset  by the change in oil  and  gas  properties  of
approximately  $3,200,  resulting  in  excess  cash  for  contingencies  or
subsequent distributions.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $952,195  have  been made to the partners.  As of September  30,  1999,
$870,145  or $308.45 per limited partner unit has been distributed  to  the
limited partners, representing a 62% return of the capital contributed.

As  of  September  30, 1999, the Partnership had approximately  $37,900  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 the 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 XI-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>