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                                FORM 10-Q


                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D.C.  20549

(MARK ONE)

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

For the quarterly period ended June 30, 2002

                                    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 & 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 16.

<PAGE>
                     PART I. - FINANCIAL INFORMATION


Item 1. Financial Statements

The  unaudited  condensed financial statements included  herein  have  been
prepared  by  the Registrant (herein also referred to as the "Partnership")
in  accordance  with generally accepted accounting principles  for  interim
financial information and with the instructions to Form 10-Q and Rule 10-01
of Regulation S-X.  Accordingly, they do not include all of the information
and  footnotes  required  by generally accepted accounting  principles  for
complete   financial  statements.   In  the  opinion  of  management,   all
adjustments necessary for a fair presentation have been included and are of
a  normal  recurring nature.  The financial statements should  be  read  in
conjunction with the audited financial statements and the notes thereto for
the  year ended December 31, 2001, which are found in the Registrant's Form
10-K  Report  for  2001 filed with the Securities and Exchange  Commission.
The December 31, 2001 balance sheet included herein has been taken from the
Registrant's  2001 Form 10-K Report.  Operating results for the  three  and
six month periods ended June 30, 2002 are not necessarily indicative of the
results that may be expected for the full year.

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

                              Balance Sheets


                                                    June 30,    December 31,
                                                      2002          2001
                                                   ---------    ------------
                                                  (unaudited)
  Assets
  ------

Current assets:
 Cash and cash equivalents                   $        11,441       13,139
 Receivable from Managing General Partner             18,942            -

---------                                    ---------
                                                 Total    current    assets
30,383                                       13,139

---------                                    ---------
Oil and gas properties - using the full-
 cost method of accounting                         1,053,467    1,054,189
  Less accumulated depreciation,
                                               depletion  and  amortization
828,555                                      817,555

---------                                    ---------
                                              Net  oil  and gas  properties
224,912                                      236,634

---------                                    ---------
                                                                          $
255,295                                      249,773

=========                                    =========

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

Current liabilities:
 Payable to Managing General Partner         $             -        2,719
 Distribution payable                                     46           46

---------                                    ---------
                                               Total   current  liabilities
46                                           2,765

---------                                    ---------

Partners' equity:
 General partners                                    (5,160)      (6,960)
 Limited partners                                    260,409      253,968

---------                                    ---------
                                                Total    partners'   equity
255,249                                      247,008

---------                                    ---------
                                                                          $
255,295                                      249,773

=========                                    =========

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

                         Statements of Operations
                               (unaudited)


                                 Three Months Ended      Six Months Ended
                                       June 30,              June 30,
                                    2002      2001        2002      2001
                                   -----     -----       -----     -----

  Revenues
  --------
Oil and gas                   $    47,262     58,870     80,296    155,726
Interest                               27        333         51        683
Miscellaneous settlement            1,236          -      1,236          -
                                  -------    -------    -------    -------
                                   48,525     59,203     81,583    156,409
                                  -------    -------    -------    -------

  Expenses
  --------
Production                         24,614     39,922     38,853     73,394
General and administrative          4,293      4,654      8,489      8,757
Depreciation, depletion and
 amortization                       7,000     14,000     11,000     23,000
                                  -------    -------    -------    -------
                                   35,907     58,576     58,342    105,151
                                  -------    -------    -------    -------
Net income                    $    12,618        627     23,241     51,258
                                  =======    =======    =======    =======
Net income (loss) allocated to:

 Managing General Partner     $     1,766      1,316      2,970      6,683
                                  =======    =======    =======    =======
 General Partner              $       196        147        330        743
                                  =======    =======    =======    =======
 Limited partners             $    10,656      (836)     19,941     43,832
                                  =======    =======    =======    =======
   Per  limited  partner unit    $        3.78           (.30)         7.07
15.54
                                  =======    =======    =======    =======

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

                         Statements of Cash Flows
                               (unaudited)


                                                        Six Months Ended
                                                             June 30,
                                                          2002      2001
                                                         -----     -----

Cash flows from operating activities:

 Cash received from oil and gas sales               $    73,890    175,551
 Cash paid to suppliers                                (62,597)   (79,910)
 Interest received                                           51        683
 Miscellaneous settlement                                 1,236          -
                                                       --------   --------
  Net cash provided by operating activities              12,580     96,324
                                                       --------   --------
Cash flows from investing activities:

 Additions to oil and gas properties                          -      (795)
 Sale of oil and gas properties                             722          -
                                                       --------   --------
  Net cash provided by
             722         (795)
                                                       --------   --------
Cash flows used in financing activities:

 Distributions to partners                             (15,000)   (98,500)
                                                       --------   --------

Net decrease in cash and cash equivalents               (1,698)    (2,971)

 Beginning of period                                     13,139     21,569
                                                       --------   --------
 End of period                                      $    11,441     18,598
                                                       ========   ========
Reconciliation of net income to net
 cash provided by operating activities:

Net income                                          $    23,241     51,258

Adjustments to reconcile net income to
 net cash provided by operating activities:

  Depreciation, depletion and amortization               11,000     23,000
  (Increase) decrease in receivables                    (6,406)     19,825
  (Decrease) increase in payables                      (15,255)      2,241
      -------                                    -------
Net cash provided by operating activities           $    12,580     96,324
                                                        =======    =======

<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.

2.   Summary of Significant Accounting Policies
     The  interim  financial information as of June 30, 2002, and  for  the
     three  and  six  months  ended June 30, 2002, 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, 2001.

<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 performing no workovers
during  2002  to  enhance  production.  The partnership  will  most  likely
experience the historical production decline of approximately 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.

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.   The  Partnership's  capitalized  cost  did  not  exceed
estimated present value of reserves as of June 30, 2002.

Under  the  units of revenue method, the Partnership computes the provision
by  multiplying the total unamortized cost of oil and gas properties by  an
overall  rate  determined by dividing (a) oil and gas revenues  during  the
period  by (b) the total future gross oil and gas revenues as estimated  by
the  Partnership's  independent petroleum consultants.   It  is  reasonably
possible  that  those estimates of anticipated future gross  revenues,  the
remaining estimated economic life of the product, or both could be  changed
significantly in the near term due to the potential fluctuation of oil  and
gas prices or production.  The depletion estimate would also be affected by
this change.


<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  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
is  not 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.

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.

<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended June 30, 2002 and 2001

The  following  table  provides certain information  regarding  performance
factors for the quarters ended June 30, 2002 and 2001:

                                               Three Months
                                                  Ended          Percentage
                                                 June 30,         Increase
                                              2002       2001    (Decrease)
                                              ----       ----    ----------
Average price per barrel of oil          $    24.12     24.31     (1%)
Average price per mcf of gas             $     2.86      4.26    (33%)
Oil production in barrels                     1,000     1,000       0%
Gas production in mcf                         8,100    10,000    (19%)
Gross oil and gas revenue                $   47,262    58,870    (20%)
Net oil and gas revenue                  $   22,648    18,948      20%
Partnership distributions                $    9,000    38,500    (77%)
Limited partner distributions            $    8,100    34,650    (77%)
Per unit distribution to limited
 partners                                $     2.87     12.28    (77%)
Number of limited partner units               2,821     2,821

Revenues

The  Partnership's oil and gas revenues decreased to $47,262  from  $58,870
for the quarters ended June 30, 2002 and 2001, respectively, a decrease  of
20%.   The principal factors affecting the comparison of the quarters ended
June 30, 2002 and 2001 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the quarter ended June 30, 2002 as  compared  to  the
    quarter ended June 30, 2001 by 1%, or $.19 per barrel, resulting  in  a
    decrease of approximately $200 in revenues.  Oil sales represented  51%
    of  total oil and gas sales during the quarter ended June 30,  2002  as
    compared to 36% during the quarter ended June 30, 2001.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 33%, or $1.40 per mcf, resulting in
    a decrease of approximately $11,300 in revenues.

    The  total  decrease in revenues due to the change in  prices  received
    from oil and gas production is approximately $11,500.  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 remained the same during the quarter ended June 30, 2002
    as compared to the quarter ended June 30, 2001.

    Gas production decreased approximately 1,900 mcf or 19% during the same
    period, resulting in a decrease of approximately $8,100 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $8,100.  The decrease in gas production is due to several
    small wells having a sharp natural decline.

Costs and Expenses

Total costs and expenses decreased to $35,907 from $58,576 for the quarters
ended  June  30,  2002  and 2001, respectively, a  decrease  of  39%.   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  38%  lower,   or
    approximately $15,300 less during the quarter ended June  30,  2002  as
    compared  to  the quarter ended June 30, 2001.  The decrease  in  lease
    operating expense is due to maintenance and repairs being performed  in
    2001,  and the decrease in production taxes in relation to the decrease
    in gross revenues received in 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 decreased 8%
    or  approximately  $400  during the quarter  ended  June  30,  2002  as
    compared to the quarter ended June 30, 2001.

3.  Depletion  expense decreased to $7,000 for the quarter ended  June  30,
    2002  from  $14,000  for the same period in 2001.   This  represents  a
    decrease  of 50%.  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.  The contributing
    factor  to  the  decrease in depletion expense between the  comparative
    periods  was  the  decrease  in oil and gas revenues  received  by  the
    Partnership during 2002 as compared to 2001.

<PAGE>
B.   General  Comparison of the Six Month Periods Ended June 30,  2002  and
2001

The  following  table  provides certain information  regarding  performance
factors for the six month periods ended June 30, 2002 and 2001:

                                                Six Months
                                                  Ended          Percentage
                                                 June 30,         Increase
                                              2002       2001    (Decrease)
                                              ----       ----    ----------
Average price per barrel of oil          $    21.86     25.25     (13%)
Average price per mcf of gas             $     2.35      5.24     (55%)
Oil production in barrels                     1,900     2,000      (5%)
Gas production in mcf                        16,500    20,100     (18%)
Gross oil and gas revenue                $   80,296   155,726     (48%)
Net oil and gas revenue                  $   41,443    82,332     (50%)
Partnership distributions                $   15,000    98,500     (85%)
Limited partner distributions            $   13,500    88,650     (85%)
Per unit distribution to limited
 partners                                $     4.79     31.43     (85%)
Number of limited partner units               2,821     2,821

Revenues

The  Partnership's oil and gas revenues decreased to $80,296 from  $155,726
for  the  six months ended June 30, 2002 and 2001, respectively, a decrease
of  48%.  The principal factors affecting the comparison of the six  months
ended June 30, 2002 and 2001 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased during the six months ended June 30, 2002 as compared to  the
    six  months ended June 30, 2001 by 13%, or $3.39 per barrel,  resulting
    in   a   decrease  of  approximately  $6,400  in  revenues.  Oil  sales
    represented 52% of total oil and gas sales during the six months  ended
    June  30, 2002 as compared to 32% during the six months ended June  30,
    2001.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 55%, or $2.89 per mcf, resulting in
    a decrease of approximately $47,700 in revenues.

    The  total  decrease in revenues due to the change in  prices  received
    from oil and gas production is approximately $54,100.  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 100 barrels or 5% during the six
    months ended June 30, 2002 as compared to the six months ended June 30,
    2001, resulting in a decrease of approximately $2,500 in revenues.

    Gas production decreased approximately 3,600 mcf or 18% during the same
    period, resulting in a decrease of approximately $18,900 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately  $21,400.   The decrease in  gas  production  is  due  to
    several small wells having a sharp natural decline.

Costs and Expenses

Total  costs  and expenses decreased to $58,342 from $105,151 for  the  six
months ended June 30, 2002 and 2001, respectively, a decrease of 45%.   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  47%  lower,   or
    approximately $34,500 less during the six months ended June 30, 2002 as
    compared to the six months ended June 30, 2001.  The decrease in  lease
    operating expense is due to maintenance and repairs being performed  in
    2001,  and the decrease in production taxes in relation to the decrease
    in gross revenues received in 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 decreased 3%
    or  approximately  $300 during the six months ended June  30,  2002  as
    compared to the six months ended June 30, 2001.

3.  Depletion  expense decreased to $11,000 for the six months  ended  June
    30,  2002 from $23,000 for the same period in 2001.  This represents  a
    decrease  of 52%.  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.  The contributing
    factor  to  the  decrease in depletion expense between the  comparative
    periods  was  the  decrease  in oil and gas revenues  received  by  the
    Partnership during 2002 as compared to 2001.


<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 $12,600  in
the six months ended June 30, 2002 as compared to approximately $96,300  in
the  six  months ended June 30, 2001.  The primary source of the 2002  cash
flow from operating activities was profitable operations.

Cash  flows  provided by (used in) investing activities were  approximately
$700  in  the  six months ended June 30, 2002 as compared to  approximately
$(800)  in the six months ended June 30, 2001.  The primary source  of  the
2002  cash  flow  from investing activities was the sale  of  material  and
equipment.

Cash  flows used in financing activities were approximately $15,000 in  the
six  months ended June 30, 2002 as compared to approximately $98,500 in the
six  months ended June 30, 2001.  The only use in financing activities  was
the distributions to partners.

Total  distributions during the six months ended June 30, 2002 were $15,000
of  which $13,500 was distributed to the limited partners and $1,500 to the
general partners.  The per unit distribution to limited partners during the
six  months ended June 30, 2002 was $4.79.  Total distributions during  the
six  months  ended  June  30,  2001  were  $98,500  of  which  $88,650  was
distributed  to  the limited partners and $9,850 to the  general  partners.
The  per unit distribution to limited partners during the six months  ended
June 30, 2001 was $31.43.

The  sources  for  the  2002  distributions of $15,000  were  oil  and  gas
operations  of  approximately  $12,600  and  the  change  in  oil  and  gas
properties of approximately $700, with the balance from available  cash  on
hand at the beginning of the period.  The source for the 2001 distributions
of  $98,500  was oil and gas operations of approximately $96,300,  and  the
change  in oil and gas properties of approximately $(800), with the balance
from available cash on hand at the beginning of the period.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $1,249,870  have  been made to the partners.   As  of  June  30,  2002,
$1,138,053 or $403.42 per limited partner unit has been distributed to  the
limited partners, representing a 81% return of the capital contributed.

As  of  June 30, 2002, the Partnership had approximately $30,400 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>
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.  The Managing General Partner is currently assessing the impact
on the partnerships financial statements.

On  October 3, 2001, the FASB issued Statement No. 144 "Accounting for  the
Impairment   or   Disposal  of  Long-Lived  Assets."   This   pronouncement
supercedes FAS 121 "Accounting for the Impairment of Long-Lived Assets  and
for  Long-Lived  Assets to Be Disposed" and eliminates the  requirement  of
Statement  121 to allocate goodwill to long-lived assets to be  tested  for
impairment.   The provisions of this statement are effective for  financial
statements issued for fiscal years beginning after December 15,  2001,  and
interim  periods  within those fiscal years.  The Managing General  Partner
believes  that  the impact from SFAS No. 144 on the Partnerships  financial
position  and  results  of operation should not be significantly  different
from that of SFAS No. 121.

     In  April 2002, FASB issued SFAS No. 145, "Rescission of SFAS  No.  4,
44,  and  64,  Amendment of SFAS No. 13, and Technical Corrections."   This
Statement   rescinds  SFAS  No.  4,  "Reporting  Gains  and   Losses   from
Extinguishment of Debt", and an amendment of that Statement, SFAS  No.  64,
"Extinguishments of Debt Made to Satisfy Sinking-Fund Requirements".   This
Statement   also   rescinds   or   amends  other   existing   authoritative
pronouncements to make various technical corrections, clarify meanings,  or
describe  their applicability under changed conditions.  This  standard  is
effective  for  fiscal years beginning after May 15,  2002.   The  Managing
General Partner believes that the adoption of this statement will not  have
a significant impact on the Partnerships financial statements.

     In  July  2002,  FASB  issued  SFAS  No.  146  "Accounting  for  Costs
Associated with Exit or Disposal Activities" which establishes requirements
for  financial accounting and reporting for costs associated with  exit  or
disposal  activities.   This standard is effective  for  exit  or  disposal
activities initiated after December 31, 2002.  The Managing General Partner
is  currently  assessing the impact of this statement on the  Partnerships'
future financial statements.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk

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


<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)  Reports on Form 8-K:

              No  reports  on Form 8-K were filed during the quarter  ended
June 30, 2002.
<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 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: August 14, 2002

<PAGE>