FORM 10-K
                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D.C.  20549
(Mark One)

[x]    Annual  report  pursuant to Section 13 or 15(d)  of  the  Securities
       Exchange Act of 1934 [Fee Required]

For the fiscal year ended December 31, 1999

                                    OR

[ ]    Transition  report pursuant to Section 13 or 15(d) of the Securities
       Exchange Act of 1934 [No Fee Required]

For the transition period from                      to

Commission File Number   0-18996

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

Delaware                                                    75-2310854
(State or other jurisdiction                             (I.R.S. Employer
of incorporation or organization)                       Identification No.)

407 N. Big Spring, Suite 300, Midland, Texas                  79701
(Address of principal executive office)                    (Zip Code)

Registrant's telephone number, including area code   (915) 686-9927

       Securities registered pursuant to Section 12(b) of the Act:

                                   None

       Securities registered pursuant to Section 12(g) of the Act:

                      limited partnership interests

Indicate by check mark whether registrant (1) has filed reports required to
be  filed  by  Section 13 or 15(d) of the Securities Exchange Act  of  1934
during  the  preceding  12  months (or for such  shorter  period  that  the
registrant was required to file such reports), and (2) has been subject  to
such filing requirements for the past 90 days:     Yes   x    No

Indicate by check mark if disclosure of delinquent filers pursuant to  Item
405  of  Regulation S-K (229.405 of this chapter) is not contained  herein,
and  will  not  be  contained,  to the best of registrant's  knowledge,  in
definitive  proxy or information statements incorporated  by  reference  in
Part III of this Form 10-K or any amendment to this Form 10-K.     [x]

The  registrant's  outstanding  securities  consist  of  Units  of  limited
partnership  interests for which there exists no established public  market
from which to base a calculation of aggregate market value.

The  total  number of pages contained in this report is 39.   There  is  no
exhibit index.

<PAGE>
                            Table of Contents

Item                                                                   Page

                                  Part I

 1.  Business                                                            3

 2.  Properties                                                          6

 3.  Legal Proceedings                                                   9

 4.  Submission of Matters to a Vote of Security Holders                 9

                                 Part II

 5.  Market for Registrant's Common Equity and Related
     Stockholder Matters                                                10

 6.  Selected Financial Data                                            11

 7.  Management's Discussion and Analysis of
     Financial Condition and Results of Operations                      12

 8.  Financial Statements and Supplementary Data                        19

 9.  Changes in and Disagreements with Accountants
     on Accounting and Financial Disclosure                             33

                                 Part III

10.  Directors and Executive Officers of the Registrant                 34

11.  Executive Compensation                                             35

12.  Security Ownership of Certain Beneficial Owners and
     Management                                                         35

13.  Certain Relationships and Related Transactions                     37

                                 Part IV

14.  Exhibits, Financial Statement Schedules, and Reports
     on Form 8-K                                                        38

     Signatures                                                         39

<PAGE>
                                  Part I


Item 1.   Business

General
Southwest   Oil  &  Gas  Income  Fund  X-A,  L.P.  (the  "Partnership"   or
"Registrant")  was organized as a Delaware limited partnership  on  January
29, 1990.  The offering of limited partnership interests began May 11, 1990
as  part of a shelf offering registered under the name Southwest Oil &  Gas
1990-91  Income Program (the "Program").  Minimum capital requirements  for
the  Partnership were met on August 15, 1990, with the offering of  limited
partnership interests concluding on November 30, 1990.  The Partnership has
no subsidiaries.

The Partnership has acquired interests in producing oil and gas properties,
and  produced and marketed the crude oil and natural gas produced from such
properties.  In most cases, the Partnership purchased working interests  in
oil  and  gas properties.  The Partnership purchased either all or part  of
the rights and obligations under various oil and gas leases.

The  principal executive offices of the Partnership are located at  407  N.
Big Spring, Suite 300, Midland, Texas, 79701.  The Managing General Partner
of  the  Partnership,  Southwest Royalties,  Inc.  (the  "Managing  General
Partner")   and  its  staff  of  97  individuals,  together  with   certain
independent  consultants  used  on an "as needed"  basis,  perform  various
services on behalf of the Partnership, including the selection of  oil  and
gas properties and the marketing of production from such properties.  H. H.
Wommack,  III,  a  stockholder, director, President and  Treasurer  of  the
Managing  General Partner, is also a general partner.  The Partnership  has
no employees.

Principal Products, Marketing and Distribution
The  Partnership has acquired and holds working interests in  oil  and  gas
properties  located  in  New  Mexico and  Texas.   All  activities  of  the
Partnership are confined to the continental United States.  All oil and gas
produced  from these properties is sold to unrelated third parties  in  the
oil and gas business.

The  revenues  generated from the Partnership's oil and gas activities  are
dependent upon the current market for oil and gas.  The prices received  by
the Partnership for its oil and gas production depend upon numerous factors
beyond   the   Partnership's  control,  including  competition,   economic,
political  and regulatory developments and competitive energy sources,  and
make it particularly difficult to estimate future prices of oil and natural
gas.

<PAGE>
Oil prices experienced a year of recovery during 1999.  After seeing prices
languish  near  $10  per barrel in December 1998, a rebound  occurred  that
would briefly push NYMEX pricing over $27 in late November 1999.  Crude oil
prices reached $20 per barrel in mid-July and would not fall below $21  the
rest of the year.  There were drastic improvements to the main factors that
gave  rise  to  the worst price depression in history.  These  improvements
provoked a spike in crude oil prices to levels not seen since the Gulf War.
First, OPEC has done a remarkable job of adhering to production cuts agreed
to  in  March, despite the temptation to cheat given current  pricing.   As
prices  have  risen  over  the last twelve months,  OPEC  has  consistently
maintained a compliance rate above 90 percent.  Also, most foreign  markets
are well on their way to recovery, greatly increasing the demand for energy
in   those  countries.   These  and  other  factors  have  eliminated   the
"oversupply"  of  crude oil that we experienced in 1998.   The  near  month
contract for crude oil settled at $25.60 per barrel on December 30, 1999.

In  1999  natural  gas  prices rose 10% to an average of  $2.18/MMBtu,  18 cents
higher  than  the  $2.00/MMBtu average seen in 1998.  Despite  warmer-than-
normal  heating seasons at both ends of the year, 1999 was the fourth  year
in  a  row that prices averaged $2.00/MMBtu or above.  Citing lower storage
levels and a rising demand for natural gas, industry experts are predicting
a "healthy jump" in prices for 2000.  Although higher prices in 1999 fueled
an  increase in production, end of year gas in storage nationwide  is  only
75% of capacity as compared to 87% at the end of 1998.  Further, gas demand
is expected to continue to increase at a faster pace than the amount of gas
being replaced.  A record breaking 70% of single-family homes built in 1999
were equipped with natural gas services ranging from traditional heating to
water   heating,   cooking  and  grilling.   Based  on  these   encouraging
statistics,  we  remain optimistic in our expectation  of  slightly  higher
natural  gas  prices in the coming year, hopefully seeing an average  above
the $2.20/MMBtu level..

Following  is a table of the ratios of revenues received from oil  and  gas
production for the last three years:

                                  Oil          Gas

                    1999          86%          14%
                    1998          87%          13%
                    1997          86%          14%

As  the table indicates, the majority of the Partnership's revenue is  from
its   oil  production;  therefore,  Partnership  revenues  will  be  highly
dependent upon the future prices and demands for oil.

Seasonality of Business
Although the demand for natural gas is highly seasonal, with higher  demand
in  the colder winter months and in very hot summer months, the Partnership
has  been able to sell all of its natural gas, either through contracts  in
place or on the spot market at the then prevailing spot market price.  As a
result,  the volumes sold by the Partnership have not fluctuated materially
with the change of season.

<PAGE>
Customer Dependence
No  material portion of the Partnership's business is dependent on a single
purchaser,  or a very few purchasers, where the loss of one  would  have  a
material adverse impact on the Partnership.  Three purchasers accounted for
73%  of  the  Partnership's  total  oil and  gas  production  during  1999:
Scurlock Permian Corporation for 27%, Navajo Refining Company for  26%  and
Eaglewing Trading Inc. for 20%.  Four purchasers accounted for 78%  of  the
Partnership's  total oil and gas production during 1998:  Scurlock  Permian
Corporation  33%, Navajo Refining Company 21%, Eaglewing Trading  Inc.  13%
and  Mobil  Corporation  11%.  Four purchasers accounted  for  76%  of  the
Partnership's  total oil and gas production during 1997:  Scurlock  Permian
Corporation  34%, Navajo Refining Company 18%, Mobil Corporation  13%,  and
Eaglewing  Trading Inc. 11%.  All purchasers of the Partnership's  oil  and
gas  production  are unrelated third parties.  In the event  any  of  these
purchasers were to discontinue purchasing the Partnership's production, the
Managing General Partner believes that a substitute purchaser or purchasers
could be located without delay.  No other purchaser accounted for an amount
equal  to  or  greater than 10% of the Partnership's sales of oil  and  gas
production.

Competition
Because  the  Partnership has utilized all of its funds available  for  the
acquisition  of interests in producing oil and gas properties,  it  is  not
subject  to  competition from other oil and gas property  purchasers.   See
Item 2, Properties.

Factors  that  may  adversely  affect the  Partnership  include  delays  in
completing  arrangements  for  the sale of production,  availability  of  a
market for production, rising operating costs of producing oil and gas  and
complying  with  applicable  water  and  air  pollution  control  statutes,
increasing  costs  and  difficulties of transportation,  and  marketing  of
competitive  fuels.   Moreover, domestic oil  and  gas  must  compete  with
imported oil and gas and with coal, atomic energy, hydroelectric power  and
other forms of energy.

Regulation

Oil  and Gas Production - The production and sale of oil and gas is subject
to  federal and state governmental regulation in several respects, such  as
existing price controls on natural gas and possible price controls on crude
oil,  regulation of oil and gas production by state and local  governmental
agencies, pollution and environmental controls and various other direct and
indirect   regulation.    Many  jurisdictions  have  periodically   imposed
limitations on oil and gas production by restricting the rate of  flow  for
oil  and  gas wells below their actual capacity to produce and by  imposing
acreage limitations for the drilling of wells.  The federal government  has
the  power  to  permit increases in the amount of oil imported  from  other
countries and to impose pollution control measures.

<PAGE>
Various  aspects of the Partnership's oil and gas activities are  regulated
by  administrative agencies under statutory provisions of the states  where
such  activities  are  conducted and by certain  agencies  of  the  federal
government for operations on Federal leases.  Moreover, certain  prices  at
which the Partnership may sell its natural gas production are controlled by
the  Natural Gas Policy Act of 1978, the Natural Gas Wellhead Decontrol Act
of  1989  and the regulations promulgated by the Federal Energy  Regulatory
Commission.

Environmental  - The Partnership's oil and gas activities  are  subject  to
extensive  federal,  state  and local laws and  regulations  governing  the
generation,  storage, handling, emission, transportation and  discharge  of
materials into the environment.  Governmental authorities have the power to
enforce compliance with their regulations, and violations carry substantial
penalties.   This  regulatory burden on the oil and gas industry  increases
its cost of doing business and consequently affects its profitability.  The
Managing  General  Partner  is  unable to  predict  what,  if  any,  effect
compliance will have on the Partnership.

Industry  Regulations  and  Guidelines - Certain industry  regulations  and
guidelines  apply to the registration, qualification and operation  of  oil
and  gas programs in the form of limited partnerships.  The Partnership  is
subject  to  these  guidelines  which regulate  and  restrict  transactions
between  the Managing General Partner and the Partnership.  The Partnership
complies  with these guidelines and the Managing General Partner  does  not
anticipate that continued compliance will have a material adverse effect on
Partnership operations.

Partnership Employees
The  Partnership has no employees; however the Managing General Partner has
a  staff of geologists, engineers, accountants, landmen and clerical  staff
who  engage in Partnership activities and operations and perform additional
services  for  the  Partnership as needed.  In  addition  to  the  Managing
General  Partner's  staff, the Partnership engages independent  consultants
such  as petroleum engineers and geologists as needed.  As of December  31,
1999,  there were 97 individuals directly employed by the Managing  General
Partner in various capacities.

Item 2.   Properties

In  determining whether an interest in a particular producing property  was
to  be  acquired, the Managing General Partner considered such criteria  as
estimated  oil  and  gas reserves, estimated cash flow  from  the  sale  of
production,  present  and  future prices of oil  and  gas,  the  extent  of
undeveloped  and  unproved reserves, the potential for secondary,  tertiary
and other enhanced recovery projects and the availability of markets.

As  of December 31, 1999, the Partnership possessed an interest in oil  and
gas  properties  located in Eddy and Lea Counties  of  New  Mexico,  Duval,
Hockley,  Midland,  Pecos,  Runnels and  Ward  Counties  of  Texas.   These
properties  consist  of various interests in approximately  169  wells  and
units.

<PAGE>
Due  to  the  Partnership's  objective of  maintaining  current  operations
without engaging in the drilling of any developmental or exploratory wells,
or additional acquisitions of producing properties, there have not been any
significant changes in properties during 1999, 1998 and 1997.

During  1999, nine leases were sold for $42,770.  During 1998, eight leases
were sold for $67,800.  During 1997, two leases were sold for $2,500.

Significant Properties
The  following  table  reflects the significant  properties  in  which  the
Partnership has an interest:

                         Date
                      Purchased           No. of        Proved Reserves**
Name and Location    and Interest         Wells     Oil (bbls)   Gas (mcf)
-----------------    ------------         ------    ----------   ---------

Texas Crude           12/90* at 17.5%       9         99,000      43,000
Acquisition           to 50% working
Gaines, Hockley,      interest
Terry and Culberson
Counties, Texas
Lea County, New
Mexico

*Per  the  terms of the purchase, the Partnership received production  runs
from a period prior to the date of purchase.

<PAGE>
*Donald  R.  Creamer,  P.E., an Independent Registered  Petroleum  Engineer
prepared  the reserve and present value data for the Partnership's existing
properties  as  of  January 1, 2000.  The reserve estimates  were  made  in
accordance  with  guidelines  established by the  Securities  and  Exchange
Commission  pursuant  to Rule 4-10(a) of Regulation S-X.   Such  guidelines
require oil and gas reserve reports be prepared under existing economic and
operating  conditions  with  no provisions for price  and  cost  escalation
except by contractual arrangements.

The  New York Mercantile Exchange price at December 31, 1999 of $25.60  was
used  as the beginning basis for the oil price.  Oil price adjustments from
$25.60  per  barrel were made in the individual evaluations to reflect  oil
quality,  gathering and transportation costs.  The results are  an  average
price received at the lease of $22.83 per barrel in the preparation of  the
reserve report as of January 1, 2000.

In  the  determination of the gas price, the New York  Mercantile  Exchange
price  at December 31, 1999 of $2.33 was used as the beginning basis.   Gas
price   adjustments  from  $2.33  per  Mcf  were  made  in  the  individual
evaluations to reflect BTU content, gathering and transportation costs  and
gas processing and shrinkage.  The results are an average price received at
the  lease of $2.18 per Mcf in the preparation of the reserve report as  of
January 1, 2000.

As  also discussed in Part II, Item 7, Management's Discussion and Analysis
of  Financial Condition and Results of Operations, oil and gas prices  were
subject to frequent changes in 1999.

The  evaluation  of  oil and gas properties is not  an  exact  science  and
inevitably involves a significant degree of uncertainty, particularly  with
respect to the quantity of oil or gas that any given property is capable of
producing.   Estimates  of  oil and gas reserves  are  based  on  available
geological and engineering data, the extent and quality of which  may  vary
in  each  case  and,  in  certain instances, may prove  to  be  inaccurate.
Consequently,  properties may be depleted more rapidly than the  geological
and engineering data have indicated.

Unanticipated  depletion, if it occurs, will result in lower reserves  than
previously  estimated; thus an ultimately lower return for the Partnership.
Basic  changes in past reserve estimates occur annually.  As  new  data  is
gathered  during the subsequent year, the engineer must revise his  earlier
estimates.  A year of new information, which is pertinent to the estimation
of  future  recoverable volumes, is available during  the  subsequent  year
evaluation.

<PAGE>
In  applying industry standards and procedures, the new data may cause  the
previous  estimates to be revised.  This revision may increase or  decrease
the  earlier estimated volumes.  Pertinent information gathered during  the
year  may  include  actual production and decline  rates,  production  from
offset wells drilled to the same geologic formation, increased or decreased
water  production, workovers, and changes in lifting costs,  among  others.
Accordingly,  reserve estimates are often different from the quantities  of
oil and gas that are ultimately recovered.

The  Partnership  has  reserves which are classified  as  proved  developed
producing, proved developed non-producing and proved undeveloped.   All  of
the  proved reserves are included in the engineering reports which evaluate
the Partnership's present reserves.

Because  the  Partnership  does  not engage  in  drilling  activities,  the
development of proved undeveloped reserves in conducted pursuant  to  farm-
out  arrangements  with  the Managing General Partner  or  unrelated  third
parties.  Generally, the Partnership retains a carried interest such as  an
overriding royalty interest under the terms of a farm-out or receives cash.

The  Partnership or the owners of properties in which the Partnership  owns
an  interest  can  engage  in workover projects or  supplementary  recovery
projects, for example, to extract behind the pipe reserves which qualify as
proved developed non-producing reserves.  See Part II, Item 7, Management's
Discussion and Analysis of Financial Condition and Results of Operations.

Item 3.   Legal Proceedings

There are no material pending legal proceedings to which the Partnership is
a party.

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

No  matter  was submitted to a vote of security holders during  the  fourth
quarter of 1999 through the solicitation of proxies or otherwise.

<PAGE>
                                 Part II


Item 5.   Market for the Registrant's Common Equity and Related Stockholder
          Matters

Market Information
Limited  partnership interests, or units, in the Partnership were initially
offered and sold for a price of $500.  Limited partner units are not traded
on  any  exchange  and there is no public or organized trading  market  for
them.  The Managing General Partner has become aware of certain limited and
sporadic transfers of units between limited partners and third parties, but
has no verifiable information regarding the prices at which such units have
been  transferred.   Further,  a transferee may  not  become  a  substitute
limited partner without the consent of the Managing General Partner.

The  Managing  General Partner has the right, but not  the  obligation,  to
purchase limited partnership units should an investor desire to sell.   The
value  of  the  unit is determined by adding the sum of (1) current  assets
less  liabilities  and  (2) the present value of the  future  net  revenues
attributable to proved reserves and by discounting the future net  revenues
at  a rate not in excess of the prime rate charged by NationsBank, N.A.  of
Midland, Texas plus one percent (1%), which value shall be further  reduced
by  a risk factor discount of no more than one-third (1/3) to be determined
by  the  Managing General Partner in its sole and absolute discretion.   In
1999,  17  limited  partner units were tendered to  and  purchased  by  the
Managing  General Partner at an average base price of $22.57 per unit.   In
1998,  75  limited  partner units were tendered to  and  purchased  by  the
Managing  General Partner at an average base price of $18.77 per unit.   In
1997,  no  limited  partner units were purchased by  the  Managing  General
Partner.

Number of Limited Partner Interest Holders
As of December 31, 1999, there were 564 holders of limited partner units in
the Partnership.

Distributions
Pursuant to Article III, Section 3.05 of the Partnership's Certificate  and
Agreement  of  Limited Partnership "Net Cash Flow" is  distributed  to  the
partners  on  a  monthly basis.  "Net Cash Flow" is defined  as  "the  cash
generated  by  the  Partnership's investments  in  producing  oil  and  gas
properties,  less  (i)  General and Administrative  Costs,  (ii)  Operating
Costs,  and  (iii) any reserves necessary to meet current  and  anticipated
needs  of  the  Partnership, as determined in the sole  discretion  of  the
Managing General Partner."

<PAGE>
There  were  no  distributions during the year  ended  December  31,  1999.
During  1998,  distributions  were  made  totaling  $32,000,  with  $28,800
distributed  to  the limited partners and $3,200 to the  general  partners.
For  the  year ended December 31, 1998, distributions of $2.75 per  limited
partner   unit   were  made,  based  upon  10,484  limited  partner   units
outstanding.  During 1997, twelve monthly distributions were made  totaling
$172,800, with $155,520 distributed to the limited partners and $17,280  to
the  general partners.  For the year ended December 31, 1997, distributions
of  $14.83  per  limited partner unit were made, based upon 10,484  limited
partner units outstanding.

Item 6.   Selected Financial Data

The  following  selected financial data for the years  ended  December  31,
1999,  1998,  1997, 1996, and 1995 should be read in conjunction  with  the
financial statements included in Item 8:

                                      Years ended December 31,
                       ------------------------------------------------------
                         1999       1998       1997       1996      1995
                         ----       ----       ----       ----      ----
Revenues           $   273,357    288,218    565,975    832,224    587,819

Net income (loss)     (26,816)  (263,850)     40,793    173,666   (97,954)

Partners' share
 of net income (loss):

  General
   partners            (1,782)   (11,946)     10,479     23,067    (1,447)

  Limited
   partners           (25,034)  (251,904)     30,314    150,599   (96,507)

Limited partners'
 net income (loss)
  per unit              (2.39)    (24.03)       2.89      14.36     (9.21)

Limited partners'
 cash distributions
  per unit                   -       2.75      14.83      13.13       8.58

Total assets       $   124,769    183,103    447,383    579,581    558,689


<PAGE>
Item 7.   Management's  Discussion and Analysis of Financial Condition  and
          Results of Operations

General
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 any net proceeds from operations to  the
general  and  limited partners.  Net revenues from producing  oil  and  gas
properties are not reinvested in other revenue producing assets  except  to
the  extent  that  producing facilities and wells  are  reworked  or  where
methods are, employed to improve or enable more efficient recovery  of  oil
and gas reserves.  The economic life of the Partnership thus depends on the
period  over  which the Partnership's oil and gas reserves are economically
recoverable.

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  farm-out arrangements and on 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  limited
partners  is therefore expected to fluctuate in later years based on  these
factors.

Based  on  current  conditions,  management anticipates  performing  a  few
workovers during 2000 to enhance production.  The partnership may  have  an
increase   in  production  volumes  for  the  year  2001,  otherwise,   the
partnership  will most likely experience the historical production  decline
of approximately 7% per year.


<PAGE>
Results of Operations

A.  General Comparison of the Years Ended December 31, 1999 and 1998

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 1999 and 1998:

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                1999      1998   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil            $   16.18    11.65      39%
Average price per mcf of gas               $    2.31     1.83      26%
Oil production in barrels                     14,550   21,500    (32%)
Gas production in mcf                         16,430   20,500    (20%)
Gross oil and gas revenue                  $ 273,357  288,182     (5%)
Net oil and gas revenue                    $  65,632 (23,689)     377%
Partnership distributions                  $       -   32,000   (100%)
Limited partner distributions              $       -   28,800   (100%)
Per unit distribution to limited partners  $       -     2.75   (100%)
Number of limited partner units               10,484   10,484

Revenues

The  Partnership's oil and gas revenues decreased to $273,357 from $288,182
for the years ended December 31, 1999 and 1998, respectively, a decrease of
5%.   The  principal factors affecting the comparison of  the  years  ended
December 31, 1999 and 1998 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the year ended December 31, 1999 as compared  to  the
    year ended December 31, 1998 by 39%, or $4.53 per barrel, resulting  in
    an   increase  of  approximately  $97,400  in  revenues.    Oil   sales
    represented  86%  of  total oil and gas sales  during  the  year  ended
    December 31, 1999 as compared to 87% during the year ended December 31,
    1998.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 26%, or $.48 per mcf, resulting  in
    an increase of approximately $9,800 in revenues.

    The  total  increase in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $107,200.   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 6,950 barrels or 32% during the
    year ended December 31, 1999 as compared to the year ended December 31,
    1998, resulting in a decrease of approximately $112,500 in revenues.

    Gas production decreased approximately 4,070 mcf or 20% during the same
    period, resulting in a decrease of approximately $9,400 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $121,900.  The decrease in production is due primarily to
    property sales and the shut-in of one gas well.

Costs and Expenses

Total  costs and expenses decreased to $300,173 from $552,068 for the years
ended  December 31, 1999 and 1998, respectively, a decrease  of  46%.   The
decrease  is  the  result  of  lower general  and  administrative  expense,
depletion expense, provision for impairment and lease operating costs.

1.    Lease  operating  costs  and production  taxes  were  33%  lower,  or
   approximately $104,100 less during the year ended December 31,  1999  as
   compared  to  the year ended December 31, 1998.  The decrease  in  lease
   operating costs are primarily due to property sales and the shut-in of one
   gas well.

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
    13% or approximately $12,400 during the year ended December 31, 1999 as
    compared to the year ended December 31, 1998.  The decrease of  general
    and  administrative  costs  were due in part to  additional  accounting
    costs  incurred  in  1998  in relation to the outsourcing  of  K-1  tax
    package  preparation and a change in auditors requiring  opinions  from
    both  the  predecessors  and  successor  auditors.   Additionally,  the
    Managing  General  Partner in its effort to cut  back  on  general  and
    administrative costs whenever and wherever possible was able to  reduce
    the  cost  of  reserve reports and K-1 tax package  preparation  during
    1999.

3.  Depletion  expense decreased to $9,000 for the year ended December  31,
    1999  from  $101,000 for the same period in 1998.   This  represents  a
    decrease  of 91%.  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.

    A  contributing factor to the decrease in depletion expense between the
    comparative periods was the increase in the price of oil and  gas  used
    to determine the Partnership's reserves for January 1, 2000 as compared
    to  1999.   Another  contributing factor  was  due  to  the  impact  of
    revisions  of  previous estimates on reserves.  Revisions  of  previous
    estimates  can be attributed to the changes in production  performance,
    oil  and  gas  price and production costs.  The impact of the  revision
    would  have  decreased depletion expense approximately  $64,000  as  of
    December 31, 1998.

4.  The  Partnership  reduced the net capitalized  costs  of  oil  and  gas
    properties  during 1998 by $43,386.  This provision for impairment  had
    the  effect  of reducing net income, but did not affect  cash  flow  or
    partner  distributions.  See Summary of Significant Accounting Policies
    - Oil and Gas Properties.

<PAGE>

Results of Operations

B.  General Comparison of the Years Ended December 31, 1998 and 1997

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 1998 and 1997:

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                1998      1997   (Decrease)
                                                ----      ----   ---------

Average price per barrel of oil            $   11.65    18.00    (35%)
Average price per mcf of gas               $    1.83     2.60    (30%)
Oil production in barrels                     21,500   26,600    (19%)
Gas production in mcf                         20,500   30,200    (32%)
Gross oil and gas revenue                  $ 288,182  557,088    (48%)
Net oil and gas revenue                    $(23,689)  183,148   (113%)
Partnership distributions                  $  32,000  172,800    (81%)
Limited partner distributions              $  28,800  155,520    (81%)
Per unit distribution to limited partners  $    2.75    14.83    (81%)
Number of limited partner units               10,484   10,484

Revenues

The  Partnership's oil and gas revenues decreased to $288,182 from $557,088
for the years ended December 31, 1998 and 1997, respectively, a decrease of
48%.   The  principal factors affecting the comparison of the  years  ended
December 31, 1998 and 1997 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the year ended December 31, 1998 as compared  to  the
    year ended December 31, 1997 by 35%, or $6.35 per barrel, resulting  in
    a   decrease  of  approximately  $168,900  in  revenues.    Oil   sales
    represented  87%  of  total oil and gas sales  during  the  year  ended
    December 31, 1998 as compared to 86% during the year ended December 31,
    1997.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 30%, or $.77 per mcf, resulting  in
    a decrease of approximately $23,300 in revenues.

    The  total  decrease in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $192,200.   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 5,100 barrels or 19% during the
    year ended December 31, 1998 as compared to the year ended December
    31, 1997, resulting in a decrease of approximately $59,400 in
    revenues.

    Gas production decreased approximately 9,700 mcf or 32% during the same
    period, resulting in a decrease of approximately $17,800 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $77,200.  The decrease in oil and gas production  is  due
    primarily to property sales and downtime and subsequent shut-ins  found
    to be uneconomical to repair.

Costs and Expenses

Total costs and expenses increased to $552,068 from $525,182 for the years
ended December 31, 1998 and 1997, respectively, an increase of 5%.  The
increase is the result of higher general and administrative expense,
depletion expense and provision for impairment, partially offset by a
decrease of lease operating costs.

1.  Lease  operating  costs  and  production  taxes  were  17%  lower,   or
    approximately $62,100 less during the year ended December 31,  1998  as
    compared  to  the  year  ended December  31,  1997.   The  decrease  is
    primarily  due to property sales, downtime and shut-ins  due  to  wells
    being uneconomical to repair.

2.  General and administrative costs consist of independent accounting  and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner  personnel costs.  General and administrative  costs  increased
    10% or approximately $8,600 during the year ended December 31, 1998  as
    compared to the year ended December 31, 1997.

3.  Depletion expense increased to $101,000 for the year ended December 31,
    1998  from  $64,000  for the same period in 1997.  This  represents  an
    increase  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.

    A  contributing factor to the increase in depletion expense between the
    comparative periods was the decrease in the price of oil and  gas  used
    to determine the Partnership's reserves for January 1, 1999 as compared
    to  1998.   Another  contributing factor  was  due  to  the  impact  of
    revisions  of  previous estimates on reserves.  Revisions  of  previous
    estimates  can be attributed to the changes in production  performance,
    oil  and  gas  price and production costs.  The impact of the  revision
    would  have  increased depletion expense approximately  $52,000  as  of
    December 31, 1997.

4.   The  Partnership  reduced the net capitalized costs  of  oil  and  gas
     properties  by $43,386.  This provision for impairment had the  effect
     of  reducing  net  income, but did not affect  cash  flow  or  partner
     distributions.  See Summary of Significant Accounting Policies  -  Oil
     and Gas Properties.

<PAGE>

C.  Revenue and Distribution Comparison

Partnership  income or (loss) for the years ended December 31,  1999,  1998
and  1997  was $(26,816), $(263,850) and $40,793, respectively.   Excluding
the  effects  of  depreciation, depletion, amortization and  provision  for
impairment,  net  income  or  (loss) would have  been  $(17,816)  in  1999,
$(119,464)  in  1998  and  $104,792 in 1997.  Correspondingly,  Partnership
distributions  for the years ended December 31, 1999, 1998  and  1997  were
none, $32,000 and $172,800, respectively.  These differences are indicative
of the changes in oil and gas prices, production and property sales.

There  were  no distributions for the year ending December 31,  1999.   The
sources  for the 1998 distributions of $32,000 were oil and gas  operations
of  approximately  $(47,400) and the change in oil and  gas  properties  of
approximately  $89,800,  resulting  in excess  cash  for  contingencies  or
subsequent  distributions.   The  sources for  the  1997  distributions  of
$172,800  were  oil and gas operations of approximately  $164,700  and  the
change  in oil and gas properties of approximately $3,800, with the balance
from available cash on hand at the beginning of the period.

There  were  no  distributions during the year ending  December  31,  1999.
Total distributions during the year ended December 31, 1998 were $32,000 of
which  $28,800  was distributed to the limited partners and $3,200  to  the
general partners.  The per unit distribution to limited partners during the
same  period was $2.75.  Total distributions during the year ended December
31,  1997  were $172,800 of which $155,520 was distributed to  the  limited
partners and $17,280 to the general partners.  The per unit distribution to
limited partners during the same period was $14.83.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $2,693,706  have been made to the partners.  As of December  31,  1999,
$2,474,805 or $236.06 per limited partner unit, has been distributed to the
limited partners, representing a 47% return of the capital contributed.

<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 or (used in) operating activities were approximately
$(57,300) in 1999 compared to $(47,375) in 1998 and approximately  $164,700
in  1997.   The primary use of the 1999 cash flow from operating activities
was for operations.

Cash  flows provided by investing activities were approximately $43,600  in
1999  compared to $89,847 in 1998 and approximately $3,800  in  1997.   The
principal  source of the 1999 cash flow from investing activities  was  the
sale of oil and gas properties.

Cash flows provided by or (used in) financing activities were approximately
$260 in 1999 compared to $(32,200) in 1998 and approximately $(173,000)  in
1997.

As  of  December  31,  1999, the Partnership had  approximately  $8,100  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.

Liquidity - Managing General Partner

The  Managing General Partner has a highly leveraged capital structure with
over  $35.1  million principal and $17.5 million interest payments  due  in
2000  on  its  debt  obligations. Due to the severely  depressed  commodity
prices  experienced  during the last quarter of 1997, throughout  1998  and
continuing through the second quarter of 1999 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  year  2000  issue  referred to the risk of disruptions  of  operations
caused  by  the  failure of computer-controlled systems, including  systems
used  by  third  parties, to properly recognize date sensitive  information
when  the  year changed from 1999 to 2000.  During the year ended  December
31, 1999, the Managing General Partners data processing subsidiary, Midland
Southwest  Software, Inc., installed new software as part  of  an  on-going
project  to upgrade its financial and management information systems.   The
cost  of  upgrading the software occurred in the normal course  of  Midland
Southwest  Software's  business and was not  material  to  the  results  of
operations or financial condition of the Partnership.

The  Partnership  has not experienced any significant business  disruptions
due  to  year  2000 issues causing processing errors in its systems,  or  a
third  party's  systems, during the period of operations after  January  1,
2000 until the filing of the 10-K.

<PAGE>
Item 8.   Financial Statements and Supplementary Data

                      Index to Financial Statements

                                                                       Page

Independent Auditors Report                                             20

Balance Sheets                                                          21

Statements of Operations                                                22

Statement of Changes in Partners' Equity                                23

Statements of Cash Flows                                                24

Notes to Financial Statements                                           26

<PAGE>









                        INDEPENDENT AUDITORS REPORT

The Partners
Southwest Oil & Gas Income Fund X-A, L.P.
(A Delaware Limited Partnership):


We  have  audited the accompanying balance sheets of Southwest  Oil  &  Gas
Income Fund X-A, L.P. (the "Partnership") as of December 31, 1999 and 1998,
and  the related statements of operations, changes in partners' equity  and
cash  flows  for each of the years in the three-year period ended  December
31,  1999.   These  financial  statements are  the  responsibility  of  the
Partnership's management.  Our responsibility is to express an  opinion  on
these financial statements based on our audits.

We  conducted  our  audits in accordance with generally  accepted  auditing
standards.  Those standards require that we plan and perform the  audit  to
obtain reasonable assurance about whether the financial statements are free
of  material  misstatement.  An audit includes examining, on a test  basis,
evidence   supporting  the  amounts  and  disclosures  in   the   financial
statements.   An  audit  also includes assessing the accounting  principles
used  and  significant estimates made by management, as well as  evaluating
the  overall financial statement presentation.  We believe that our  audits
provide a reasonable basis for our opinion.

In  our opinion, the financial statements referred to above present fairly,
in  all  material respects, the financial position of Southwest Oil  &  Gas
Income  Fund X-A, L.P. as of December 31, 1999 and 1998 and the results  of
its  operations and its cash flows for each of the years in the  three-year
period  ended  December  31,  1999 in conformity  with  generally  accepted
accounting principles.








                                                  KPMG LLP



Midland, Texas
March 10, 2000

<PAGE>
                Southwest Oil & Gas Income Fund X-A, L.P.
                     (a Delaware limited partnership)
                              Balance Sheets
                        December 31, 1999 and 1998


                                                      1999          1998
                                                      ----          ----

  Assets

Current assets:
 Cash and cash equivalents                   $         1,204       14,672
 Receivable from Managing General Partner              7,752            -

---------                                    ---------
                                                 Total    current    assets
8,956                                        14,672

---------                                    ---------
Oil and gas properties - using the full-
 cost method of accounting                         3,803,199    3,846,817
  Less accumulated depreciation,
                                               depletion  and  amortization
3,687,386                                    3,678,386

---------                                    ---------
                                              Net  oil  and gas  properties
115,813                                      168,431

---------                                    ---------
                                                                          $
124,769                                      183,103

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

  Liabilities and Partners' Equity

Current liabilities
 Distributions payable                       $           811          551
 Payable to Managing General Partner                       -       31,778

---------                                    ---------
                                               Total   current  liabilities
811                                          32,329

---------                                    ---------
Partners' equity:
 General partners                                   (28,577)     (26,795)
 Limited partners                                    152,535      177,569

---------                                    ---------
                                                Total    partners'   equity
123,958                                      150,774

---------                                    ---------
                                                                          $
124,769                                      183,103

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


















                  The accompanying notes are an integral
                   part of these financial statements.

<PAGE>
                Southwest Oil & Gas Income Fund X-A, L.P.
                     (a Delaware limited partnership)
                         Statements of Operations
               Years ended December 31, 1999, 1998 and 1997


                                                 1999      1998     1997
                                                 ----      ----     ----
  Revenues

Oil and gas income                        $    273,357   288,182  557,088
Interest                                             -        33    1,234
Miscellaneous income                                 -         3    7,653
                                                                    -------
-------                                   ---------
                                                                    273,357
288,218                                   565,975
                                                                    -------
-------                                   ---------

  Expenses

Production                                     207,725   311,871  373,940
General and administrative                      83,448    95,811   87,242
Depreciation, depletion and amortization         9,000   101,000   64,000
Provision for impairment of oil and gas
 properties                                          -    43,386        -
                                                                    -------
-------                                   ---------
                                                                    300,173
552,068                                   525,182
                                                                    -------
-------                                   ---------
Net income (loss)                         $   (26,816) (263,850)   40,793
                                                                    =======
=======                                   =========

Net income (loss) allocated to:

 Managing General Partner                 $    (1,604)  (10,751)    9,431
                                                                    =======
=======                                   =========
 General Partner                          $      (178)   (1,195)    1,048
                                                                    =======
=======                                   =========
 Limited partners                         $   (25,034) (251,904)   30,314
                                                                    =======
=======                                   =========
  Per limited partner unit                $      (2.39)   (24.03)    2.89
                                                                    =======
=======                                   =========





















                  The accompanying notes are an integral
                   part of these financial statements.

<PAGE>
                Southwest Oil & Gas Income Fund X-A, L.P.
                     (a Delaware limited partnership)
                 Statement of Changes in Partners' Equity
               Years ended December 31, 1999, 1998 and 1997


                                               General   Limited
                                               Partners  Partners   Total
                                               --------  --------   -----
Balance at December 31, 1996              $    (4,848)   583,479  578,631

 Net income                                     10,479    30,314   40,793

 Distributions                                (17,280) (155,520)(172,800)
                                                                    -------
---------                                 ---------
Balance at December 31, 1997                  (11,649)   458,273  446,624

 Net income (loss)                            (11,946) (251,904)(263,850)

 Distributions                                 (3,200)  (28,800) (32,000)
                                                                    -------
---------                                 ---------
Balance at December 31, 1998                  (26,795)   177,569  150,774

 Net income (loss)                             (1,782)  (25,034) (26,816)

 Distributions                                       -         -        -
                                                                    -------
---------                                 ---------
Balance at December 31, 1999              $   (28,577)   152,535  123,958
                                                                    =======
=========                                 =========































                  The accompanying notes are an integral
                   part of these financial statements.

<PAGE>
                Southwest Oil & Gas Income Fund X-A, L.P.
                     (a Delaware limited partnership)
                         Statements of Cash Flows
              Years ended December 31, 1999, 1998 and 1997


                                                 1999      1998      1997
                                                 ----      ----      ----

Cash flows from operating activities:

 Cash received from oil and gas sales     $    248,321   337,610  630,437
 Cash paid to Managing General Partner
  for administrative fees and general
                                            and   administrative   overhead
(305,667)                                 (385,018)(466,972)
 Interest received                                   -        33    1,234
                                                                   --------
--------                                  --------
  Net cash provided by (used in) operating
                                           activities    (57,346)  (47,375)
164,699
                                                                   --------
--------                                  --------
Cash flows from investing activities:

 Additions to oil and gas properties           (1,252)         - (11,889)
 Sale of oil and gas properties                 44,870    89,847   15,670
                                                                   --------
--------                                  --------
   Net  cash provided by investing activities               43,618   89,847
3,781
                                                                   --------
--------                                  --------
Cash flows provided by (used in) financing
 activities:

 Distributions to partners                         260  (32,208)(172,991)
                                                                   --------
--------                                  --------
Net increase (decrease) in cash and
 cash equivalents                             (13,468)    10,264  (4,511)

 Beginning of year                              14,672     4,408    8,919
                                                                   --------
--------                                  --------
 End of year                              $      1,204    14,672    4,408
                                                                   ========
========                                  ========


(continued)




















                  The accompanying notes are an integral
                   part of these financial statements.

<PAGE>
                Southwest Oil & Gas Income Fund X-A, L.P.
                     (a Delaware limited partnership)
                   Statements of Cash Flows, continued
               Years ended December 31, 1999, 1998 and 1997


                                                 1999      1998      1997
                                                 ----      ----      ----

Reconciliation of net income (loss) to
 net cash provided by (used in)
 operating activities:

Net income (loss)                         $   (26,816) (263,850)   40,793

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

   Depreciation, depletion and amortization                 9,000   101,000
64,000
  Provision of impairment of oil and gas
                                           Properties           -    43,386
-
  (Increase) decrease in receivables          (25,036)    49,425   65,696
  Increase (decrease) in payables             (14,494)    22,664  (5,790)
                                                                    -------
-------                                   -------
Net cash provided by (used in) operating
 activities                               $   (57,346)  (47,375)  164,699
                                                                    =======
=======                                   =======

































                  The accompanying notes are an integral
                    part of these financial statements.

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

                      Notes to Financial Statements


1.   Organization
     Southwest  Oil and Gas Income Fund X-A, L.P. was organized  under  the
     laws of the state of Delaware on January 29, 1990, 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 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%           -
     Syndication costs                               100%           -
     Amortization of organization 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 as 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.

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

                      Notes to Financial Statements


2.   Summary of Significant Accounting Policies

     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.

     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.

     Should the net capitalized costs exceed the estimated present value of
     oil  and  gas reserves, discounted at 10%, such excess costs would  be
     charged  to current expense. As of December 31, 1999 and 1997 the  net
     capitalized  costs did not exceed the estimated present value  of  oil
     and  gas  reserves.   As December 31, 1998, the net  capitalized  cost
     exceeded the estimated present value of oil and gas reserves, thus  an
     adjustment of $43,386 was made to the financial statement.

     Estimates and Uncertainties
     The  preparation of financial statements in conformity with  generally
     accepted  accounting principles requires management to make  estimates
     and  assumptions  that  affect  the reported  amounts  of  assets  and
     liabilities and disclosure of contingent assets and liabilities at the
     date  of the financial statements and the reported amounts of revenues
     and expenses during the reporting period.  Actual results could differ
     from those estimates.

     Syndication Costs
     Syndication  costs  are  accounted for as a reduction  of  partnership
     equity.

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

                      Notes to Financial Statements


2.   Summary of Significant Accounting Policies - continued

     Environmental Costs
     The  Partnership  is  subject to extensive federal,  state  and  local
     environmental laws and regulations.  These laws, which are  constantly
     changing, regulate the discharge of materials into the environment and
     may  require  the Partnership to remove or mitigate the  environmental
     effects of the disposal or release of petroleum or chemical substances
     at   various  sites.   Environmental  expenditures  are  expensed   or
     capitalized  depending on their future economic benefit.  Costs  which
     improve a property as compared with the condition of the property when
     originally  constructed  or acquired and costs  which  prevent  future
     environmental contamination are capitalized.  Expenditures that relate
     to  an  existing condition caused by past operations and that have  no
     future  economic benefits are expensed.  Liabilities for  expenditures
     of  a  non-capital  nature are recorded when environmental  assessment
     and/or  remediation  is  probable and  the  costs  can  be  reasonably
     estimated.

     Gas Balancing
     The  Partnership  utilizes the sales method  of  accounting  for  gas-
     balancing  arrangements.  Under this method the Partnership recognizes
     sales  revenue  on all gas sold.  As of December 31,  1999,  1998  and
     1997, there were no significant amounts of imbalance in terms of units
     and value.

     Income Taxes
     No  provision  for  income  taxes  is  reflected  in  these  financial
     statements, since the tax effects of the Partnership's income or  loss
     are passed through to the individual partners.

     In   accordance  with  the  requirements  of  Statement  of  Financial
     Accounting  Standards  No. 109, "Accounting  for  Income  Taxes",  the
     Partnership's tax basis in its net oil and gas properties at  December
     31,  1999  and 1998 is $74,231 and $185,188, respectively,  more  than
     that  shown  on  the  accompanying Balance Sheets in  accordance  with
     generally accepted accounting principles.

     Cash and Cash Equivalents
     For purposes of the statement of cash flows, the Partnership considers
     all  highly liquid debt instruments purchased with a maturity of three
     months or less to be cash equivalents.  The Partnership maintains  its
     cash at one financial institution.

     Number of Limited Partner Units
     As  of  December  31,  1999, 1998 and 1997 there were  10,484  limited
     partner units outstanding held by 564, 570 and 570 partners.

     Concentrations of Credit Risk
     The  Partnership is subject to credit risk through trade  receivables.
     Although  a  substantial portion of its debtors'  ability  to  pay  is
     dependent upon the oil and gas industry, credit risk is minimized  due
     to  a  large customer base.  All partnership revenues are received  by
     the   Managing  General  Partner  and  subsequently  remitted  to  the
     partnership and all expenses are paid by the Managing General  Partner
     and subsequently reimbursed by the partnership.

     Fair Value of Financial Instruments
     The  carrying amount of cash and accounts receivable approximates fair
     value due to the short maturity of these instruments.

     Net Income (loss) per limited partnership unit
     The  net  income (loss) per limited partnership unit is calculated  by
     using the number of outstanding limited partnership units.

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

                      Notes to Financial Statements


3.   Liquidity - Managing General Partner
     The  Managing General Partner has a highly leveraged capital structure
     with  over $35.1 million principal and $17.5 million interest payments
     due  in  2000 on its debt obligations.  Due to the severely  depressed
     commodity  prices  experienced  during  the  last  quarter  of   1997,
     throughout 1998 and continuing through the second quarter of 1999  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.

4.   Commitments and Contingent Liabilities
     The Managing General Partner has the right, but not the obligation, to
     purchase limited partnership units should an investor desire to  sell.
     The  value of the unit is determined by adding the sum of (1)  current
     assets  less liabilities and (2) the present value of the  future  net
     revenues attributable to proved reserves and by discounting the future
     net  revenues  at  a rate not in excess of the prime rate  charged  by
     NationsBank, N.A. of Midland, Texas plus one percent (1%), which value
     shall be further reduced by a risk factor discount of no more than one-
     third  (1/3) to be determined by the Managing General Partner  in  its
     sole and absolute discretion.

     The  Partnership  is  subject  to various  federal,  state  and  local
     environmental  laws  and  regulations, which establish  standards  and
     requirements  for  protection  of the  environment.   The  Partnership
     cannot  predict the future impact of such standards and  requirements,
     which  are  subject to change and can have retroactive  effectiveness.
     The  Partnership  continues to monitor the status of  these  laws  and
     regulations.

     As  of December 31, 1999, the Partnership has not been fined, cited or
     notified  of any environmental violations and management is not  aware
     of  any  unasserted  violations which would have  a  material  adverse
     effect upon capital expenditures, earnings or the competitive position
     in  the  oil and gas industry.  However, the Managing General  Partner
     does  recognize  by  the very nature of its business,  material  costs
     could be incurred in the near term to bring the Partnership into total
     compliance.   The amount of such future expenditures is  not  reliably
     determinable  due to several factors, including the unknown  magnitude
     of  possible  contaminations, the unknown timing  and  extent  of  the
     corrective  actions  which may be required, the determination  of  the
     Partnership's  liability in proportion to, other  responsible  parties
     and  the  extent  to  which  such expenditures  are  recoverable  from
     insurance  or  indemnifications  from prior  owners  of  Partnership's
     properties.

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

                                                                Notes    to
                                                                Financial
                                                                Statements


5.   Related Party Transactions
     A  significant  portion  of the oil and gas properties  in  which  the
     Partnership  has  an interest are operated by and purchased  from  the
     Managing General Partner.  As is usual in the industry and as provided
     for  in  the  operating  agreement for each  respective  oil  and  gas
     property  in  which the Partnership has an interest, the  operator  is
     paid  an  amount for administrative overhead attributable to operating
     such  properties,  with such amounts to Southwest Royalties,  Inc.  as
     operator  approximating $56,700, $70,200 and  $66,000  for  the  years
     ended  December 31, 1999, 1998 and 1997, respectively.   In  addition,
     the  Managing  General Partner and certain officers and employees  may
     have  an interest in some of the properties that the Partnership  also
     participates.

     Certain  subsidiaries  or affiliates of the Managing  General  Partner
     perform  various  oilfield  services  for  properties  in  which   the
     Partnership  owns an interest.  Such services aggregated approximately
     $3,200, $1,900 and $1,500 for the years ended December 31, 1999,  1998
     and 1997, respectively, and the Managing General Partner believes that
     these  costs are comparable to similar charges paid by the Partnership
     to unrelated third parties.

     Southwest  Royalties,  Inc., the Managing General  Partner,  was  paid
     $78,000  during  1999,  1998 and 1997, as an administrative  fee,  for
     indirect general and administrative overhead expenses.

     Receivables  (Payable)  from  (to)  Southwest  Royalties,  Inc.,   the
     Managing  General Partner, of approximately $7,800 and  $(31,800)  are
     from  oil  and  gas  production,  net of  lease  operating  costs  and
     production taxes, as of December 31, 1999 and 1998, respectively.

     In addition, a director and officer of the Managing General Partner is
     a  partner  in a law firm, with such firm providing legal services  to
     the  Partnership  approximately $200 for the year ended  December  31,
     1999.   There  were  no legal services provided for  the  years  ended
     December 31, 1998 and 1997.

6.   Major Customers
     No  material portion of the Partnership's business is dependent  on  a
     single  purchaser, or a very few purchasers, where  the  loss  of  one
     would  have  a  material  adverse impact on  the  Partnership.   Three
     purchasers  accounted for 73% of the Partnership's total oil  and  gas
     production during 1999:  Scurlock Permian Corporation for 27%,  Navajo
     Refining  Company for 26% and Eaglewing Trading Inc.  for  20%.   Four
     purchasers  accounted for 78% of the Partnership's total oil  and  gas
     production  during  1998:  Scurlock Permian Corporation   33%,  Navajo
     Refining Company 21%, Eaglewing Trading Inc. 13% and Mobil Corporation
     11%.  Four purchasers accounted for 76% of the Partnership's total oil
     and  gas  production during 1997:  Scurlock Permian Corporation   34%,
     Navajo  Refining  Company 18%, Mobil Corporation  13%,  and  Eaglewing
     Trading  Inc. 11%.  All purchasers of the Partnership's  oil  and  gas
     production  are unrelated third parties.  In the event  any  of  these
     purchasers   were   to   discontinue  purchasing   the   Partnership's
     production,  the Managing General Partner believes that  a  substitute
     purchaser  or  purchasers could be located without  delay.   No  other
     purchaser accounted for an amount equal to or greater than 10% of  the
     Partnership's sales of oil and gas production.


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

                      Notes to Financial Statements


7.   Estimated Oil and Gas Reserves (unaudited)
     The  Partnership's  interest in proved oil  and  gas  reserves  is  as
     follows:

                                                    Oil (bbls)    Gas (mcf)
                                                    ----------    ---------
     Proved developed and undeveloped reserves -

     January 1, 1997                                 314,000       253,000

       Revisions of previous estimates             (106,000)        10,000
       Production                                   (27,000)      (30,000)
                                                     -------       -------
     December 31, 1997                               181,000       233,000

       Sales of reserves in place                    (7,000)       (8,000)
       Revisions of previous estimates             (114,000)      (57,000)
       Production                                   (22,000)      (21,000)
                                                     -------       -------
     December 31, 1998                                38,000       147,000

       Revisions of previous estimates               120,000        32,000
       Production                                   (15,000)      (16,000)
                                                     -------       -------
     December 31, 1999                               143,000       163,000
                                                     =======       =======

     Proved developed reserves -

     December 31, 1997                               181,000       228,000
                                                     =======       =======
     December 31, 1998                                37,000       138,000
                                                     =======       =======
     December 31, 1999                               142,000       155,000
                                                     =======       =======

     All  of  the Partnership's reserves are located within the continental
     United States.

     *Donald R. Creamer, P.E., an Independent Registered Petroleum Engineer
     prepared  the  reserve  and present value data for  the  Partnership's
     existing properties as of January 1, 2000.  The reserve estimates were
     made  in accordance with guidelines established by the Securities  and
     Exchange Commission pursuant to Rule 4-10(a) of Regulation S-X.   Such
     guidelines  require  oil  and gas reserve reports  be  prepared  under
     existing  economic  and operating conditions with  no  provisions  for
     price and cost escalation except by contractual arrangements.

     The  New York Mercantile Exchange price at December 31, 1999 of $25.60
     was  used  as  the  beginning basis for  the  oil  price.   Oil  price
     adjustments  from  $25.60  per  barrel were  made  in  the  individual
     evaluations  to  reflect  oil  quality, gathering  and  transportation
     costs.   The  results are an average price received at  the  lease  of
     $22.83  per  barrel  in the preparation of the reserve  report  as  of
     January 1, 2000.

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

                      Notes to Financial Statements


7.   Estimated Oil and Gas Reserves (unaudited) - continued
     In  the  determination  of  the gas price,  the  New  York  Mercantile
     Exchange price at December 31, 1999 of $2.33 was used as the beginning
     basis.   Gas  price adjustments from $2.33 per Mcf were  made  in  the
     individual   evaluations  to  reflect  BTU  content,   gathering   and
     transportation  costs and gas processing and shrinkage.   The  results
     are  an  average price received at the lease of $2.18 per Mcf  in  the
     preparation of the reserve report as of January 1, 2000.

     The  evaluation of oil and gas properties is not an exact science  and
     inevitably  involves a significant degree of uncertainty, particularly
     with respect to the quantity of oil or gas that any given property  is
     capable of producing.  Estimates of oil and gas reserves are based  on
     available  geological and engineering data, the extent and quality  of
     which may vary in each case and, in certain instances, may prove to be
     inaccurate.   Consequently, properties may be  depleted  more  rapidly
     than the geological and engineering data have indicated.

     Unanticipated  depletion, if it occurs, will result in lower  reserves
     than  previously estimated; thus an ultimately lower  return  for  the
     Partnership.  Basic changes in past reserve estimates occur  annually.
     As  new data is gathered during the subsequent year, the engineer must
     revise  his  earlier estimates.  A year of new information,  which  is
     pertinent  to  the  estimation  of  future  recoverable  volumes,   is
     available during the subsequent year evaluation.  In applying industry
     standards  and  procedures,  the  new  data  may  cause  the  previous
     estimates  to be revised.  This revision may increase or decrease  the
     earlier estimated volumes.  Pertinent information gathered during  the
     year  may include actual production and decline rates, production from
     offset  wells  drilled  to the same geologic formation,  increased  or
     decreased  water production, workovers, and changes in lifting  costs,
     among others.  Accordingly, reserve estimates are often different from
     the quantities of oil and gas that are ultimately recovered.

     The  Partnership has reserves which are classified as proved developed
     producing, proved developed non-producing and proved undeveloped.  All
     of  the proved reserves are included in the engineering reports  which
     evaluate the Partnership's present reserves.

     Because  the  Partnership does not engage in drilling activities,  the
     development  of proved undeveloped reserves in conducted  pursuant  to
     farm-out  arrangements with the Managing General Partner or  unrelated
     third  parties.  Generally, the Partnership retains a carried interest
     such  as  an overriding royalty interest under the terms of a farm-out
     or receives cash.

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

                      Notes to Financial Statements


7.   Estimated Oil & Gas Reserves (unaudited) - continued
     The  standardized measure of discounted future net cash flows relating
     to  proved oil and gas reserves at December 31, 1999, 1998 and 1997 is
     presented below:

                                              1999      1998         1997
                                              ----      ----        -----

     Future cash inflows                $  3,629,000    604,000  3,488,000
     Production and development costs      2,097,000    359,000  2,133,000
                                           ---------  ---------  ---------
     Future net cash flows                 1,532,000    245,000  1,355,000
     10% annual discount for estimated
       timing of cash flows                  609,000     77,000    484,000
                                           ---------  ---------  ---------
     Standardized measure of discounted
       future net cash flows            $    923,000    168,000    871,000
                                           =========  =========  =========

     The  principal  sources  of  change in  the  standardized  measure  of
     discounted  future  net cash flows for the years  ended  December  31,
     1999, 1998 and 1997 are as follows:

                                             1999        1998        1997
                                             ----        ----        ----

     Sales of oil and gas produced,
       net of production costs          $  (66,000)      23,000  (183,000)
      Changes in prices and production costs             172,000  (523,000)
(1,157,000)
     Changes of production rates
       (timing) and others                 (48,000)      79,000   (49,000)
     Sales of minerals in place                   -    (32,000)          -
     Revisions of previous
     quantities estimates                   680,000   (337,000)  (412,000)
     Accretion of discount                   17,000      87,000    243,000
     Discounted future net
       cash flows -
      Beginning of year                     168,000     871,000  2,429,000
                                          ---------   ---------  ---------
      End of year                       $   923,000     168,000    871,000
                                          =========   =========  =========

     Future  net cash flows were computed using year-end prices  and  costs
     that  related  to existing proved oil and gas reserves  in  which  the
     Partnership has mineral interests.

Item 9.   Changes  in and Disagreements With Accountants on Accounting  and
          Financial Disclosure

None

<PAGE>
                                 Part III

Item 10.  Directors and Executive Officers of the Registrant

Management of the Partnership is provided by Southwest Royalties, Inc.,  as
Managing  General Partner.  The names, ages, offices, positions and  length
of  service of the directors and executive officers of Southwest Royalties,
Inc. are set forth below.  Each director and executive officer serves for a
term  of  one year.  The present directors of the Managing General  Partner
have served in their capacity since the Company's formation in 1983.

     Name                   Age                      Position
--------------------        ---         -----------------------------------
-------
H. H. Wommack, III                      44     Chairman   of   the   Board,
                                        President,
                                        Chief Executive Officer, Treasurer
                                        and Director

H. Allen Corey              43          Secretary and Director

Bill E. Coggin                          45     Vice  President  and   Chief
                                        Financial Officer

J. Steven Person            41          Vice President, Marketing

Paul L. Morris              58          Director

H.  H.  Wommack, III, is Chairman of the Board, President, Chief  Executive
Officer,  Treasurer, principal stockholder and a director of  the  Managing
General  Partner,  and  has  served as its President  since  the  Company's
organization  in August, 1983.  Prior to the formation of the Company,  Mr.
Wommack  was  a  self-employed  independent oil  producer  engaged  in  the
purchase  and sale of royalty and working interests in oil and gas  leases,
and  the drilling of exploratory and developmental oil and gas wells.   Mr.
Wommack  holds  a J.D. degree from the University of Texas  from  which  he
graduated  in  1980, and a B.A. from the University of  North  Carolina  in
1977.

H.  Allen  Corey, a founder of the Managing General Partner, has served  as
the   Managing  General  Partner's  secretary  and  a  director  since  its
inception.   Mr. Corey is President of Trolley Barn Brewery, Inc.,  a  brew
pub restaurant chain based in the Southeast.  Prior to his involvement with
Trolley Barn, Mr. Corey was a partner at the law firm of Miller & Martin in
Chattanooga,  Tennessee.  He is currently of counsel to  the  law  firm  of
Baker,  Donelson,  Bearman  & Caldwell, with the  offices  in  Chattanooga,
Tennessee.  Mr. Corey received a J.D. degree from the Vanderbilt University
Law  School and B.A. degree from the University of North Carolina at Chapel
Hill.

Bill  E. Coggin, Vice President and Chief Financial Officer, has been  with
the Managing General Partner since 1985.  Mr. Coggin was Controller for Rod
Ric  Corporation of Midland, Texas, an oil and gas drilling company, during
the latter part of 1984.  He was Controller for C.F. Lawrence & Associates,
Inc., an independent oil and gas operator also of Midland, Texas during the
early  part of 1984.  Mr. Coggin taught public school for four years  prior
to his business experience.  Mr. Coggin received a B.S. in Education and  a
B.B.A. in Accounting from Angelo State University.

J.  Steven  Person, Vice President, Marketing, assumed his responsibilities
with  the Managing General Partner as National Marketing Director in  1989.
Prior  to joining the Managing General Partner, Mr. Person served  as  Vice
President  of  Marketing  for CRI, Inc., and was  associated  with  Capital
Financial  Group and Dean Witter (1983).  He received a B.B.A. from  Baylor
University in 1982 and an M.D.A. from Houston Baptist University in 1987.

Paul  L.  Morris has served as a Director of Southwest Royalties  Holdings,
Inc.  since August 1998 and Southwest Royalties, Inc. since September 1998.
Mr. Morris is President and CEO of Wagner & Brown, Ltd., one of the largest
independently owned oil and gas companies in the United States.   Prior  to
his  position with Wagner & Brown, Mr. Morris served as President of Banner
Energy and in various managerial positions with Columbia Gas System, Inc.


<PAGE>
Key Employees

Jon  P. Tate, Vice President, Land and Assistant Secretary, age 42, assumed
his  responsibilities with the Managing General Partner in 1989.  Prior  to
joining  the  Managing  General Partner, Mr.  Tate  was  employed  by  C.F.
Lawrence  & Associates, Inc., an independent oil and gas company,  as  Land
Manager from 1981 through 1989.  Mr. Tate is a member of the Permian  Basin
Landman's  Association and received his B.B.S. degree  from  Hardin-Simmons
University.

R.  Douglas  Keathley,  Vice President, Operations,  age  44,  assumed  his
responsibilities with the Managing General Partner as a Production Engineer
in  October,  1992.   Prior to joining the Managing  General  Partner,  Mr.
Keathley  was  employed for four (4) years by ARCO Oil  &  Gas  Company  as
senior  drilling  engineer working in all phases of well production  (1988-
1992),  eight  (8)  years by Reading & Bates Petroleum  Company  as  senior
petroleum  engineer responsible for drilling (1980-1988) and two (2)  years
by  Tenneco Oil Company as drilling engineer responsible for all phases  of
drilling   (1978-1980).   Mr.  Keathley  received  his  B.S.  in  Petroleum
Engineering in 1977 from the University of Oklahoma.

In certain instances, the Managing General Partner will engage professional
petroleum   consultants   and  other  independent  contractors,   including
engineers   and   geologists  in  connection  with  property  acquisitions,
geological  and  geophysical  analysis,  and  reservoir  engineering.   The
Managing  General Partner believes that, in addition to its own  "in-house"
staff,  the utilization of such consultants and independent contractors  in
specific  instances  and  on  an  "as-needed"  basis  allows  for   greater
flexibility  and greater opportunity to perform its oil and gas  activities
more economically and effectively.

Item 11.  Executive Compensation

The  Partnership  does not have any directors or executive  officers.   The
executive officers of the Managing General Partner do not receive any  cash
compensation,  bonuses, deferred compensation or compensation  pursuant  to
any  type  of  plan, from the Partnership.  The Managing  General  Partners
received  $78,000  during 1999, 1998 and 1997 as an  annual  administrative
fee.

Item 12.  Security Ownership of Certain Beneficial Owners and Management

There  are  no  limited partners who own of record, or  are  known  by  the
Managing General Partner to beneficially own, more than five percent of the
Partnership's limited partnership interests.

The  Managing  General Partner owns a nine percent interest  as  a  general
partner.   Through prior purchases, the Managing General Partner also  owns
124  limited  partner  units,  or  a 1.2% limited  partner  interest.   The
Managing  General  Partner  total  percentage  interest  ownership  in  the
Partnership is 9.6%.

No  officer or director of the Managing General Partner owns Units  in  the
Partnership.  H. H. Wommack, III, as the individual general partner of  the
Partnership,  owns  a  one  percent interest as  a  general  partner.   The
officers  and  directors  of the Managing General  Partner  are  considered
beneficial  owners of the limited partner units acquired  by  the  Managing
General  Partner by virtue of their status as such.  A list  of  beneficial
owners  of limited partner units, acquired by the Managing General Partner,
is as follows:

<PAGE>
                                                   Amount and
                                                   Nature of      Percent
                     Name and Address of           Beneficial        of
 Title of Class        Beneficial Owner            Ownership       Class
-------------------  ---------------------------  ---------------  -------
Limited Partnership  Southwest Royalties, Inc.    Directly Owns    1.2%
 Interest            Managing General Partner     124 Units
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  H. H. Wommack, III           Indirectly Owns  1.2%
 Interest            Chairman of the Board,       124 Units
                     President, CEO, Treasurer
                     and Director of Southwest
                     Royalties, Inc., the
                     Managing General Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  H. Allen Corey               Indirectly Owns  1.2%
 Interest            Secretary and Director of    124 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     633 Chestnut Street
                     Chattanooga, TN  37450-1800

Limited Partnership  Bill E. Coggin               Indirectly Owns  1.2%
 Interest            Vice President and CFO of    124 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  J. Steven Person             Indirectly Owns  1.2%
 Interest            Vice President, Marketing    124 Units
                     of Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701


Limited Partnership  Paul L. Morris               Indirectly Owns  1.2%
 Interest            Director of Southwest        124 Units
                     Royalties, Inc., the
                     Managing General Partner
                     407 N. Big Spring Street
                     Midland, TX  79701


There  are no arrangements known to the Managing General Partner which  may
at a subsequent date result in a change of control of the Partnership.

<PAGE>
Item 13.  Certain Relationships and Related Transactions

In 1999, the Managing General Partner received $78,000 as an administrative
fee.   This  amount  is  part  of the general and  administrative  expenses
incurred by the Partnership.

In  some  instances the Managing General Partner and certain  officers  and
employees  may  be working interest owners in an oil and  gas  property  in
which  the Partnership also has a working interest.  Certain properties  in
which  the Partnership has an interest are operated by the Managing General
Partner,  who  was  paid approximately $56,700 for administrative  overhead
attributable to operating such properties during 1999.

Certain  subsidiaries or affiliates of the Managing General Partner perform
various  oilfield services for properties in which the Partnership owns  an
interest.  Such services aggregated approximately $3,200 for the year ended
December 31, 1999.

In  the  opinion  of  management, the terms of the above  transactions  are
similar to ones with unaffiliated third parties.

<PAGE>
                                 Part IV


Item 14.  Exhibits, Financial Statement Schedules and Reports on Form 8-K

          (a)(1)  Financial Statements:

                  Included in Part II of this report --

                  Independent Auditors Report
                  Balance Sheets
                  Statements of Operations
                  Statement of Changes in Partners' Equity
                  Statements of Cash Flows
                  Notes to Financial Statements

                     (2)  Schedules required by Article 12 of Regulation S-
                  X  are either omitted because they are not applicable  or
                  because  the  required  information  is  shown   in   the
                  financial statements or the notes thereto.

             (3)  Exhibits:

                                      4      (a)   Certificate  of  Limited
                          Partnership of Southwest Oil & Gas Income Fund X-
                          A,  L.P.,  dated January 29, 1990.  (Incorporated
                          by reference from Partnership's Form 10-K for the
                          fiscal year ended December 31, 1990.)

                                            (b)    Agreement   of   Limited
                          Partnership of Southwest Oil & Gas Income Fund X-
                          A, L.P. dated January 29, 1990.  (Incorporated by
                          reference  from Partnership's Form 10-K  for  the
                          fiscal year ended December 31, 1990.)

                  27 Financial Data Schedule

          (b)     Reports on Form 8-K

                  There  were  no  reports filed on  Form  8-K  during  the
              quarter ended December 31, 1999.

<PAGE>
                                Signatures


Pursuant  to  the  requirements of Section 13 or 15(d)  of  the  Securities
Exchange  Act  of 1934, the Partnership has duly caused this report  to  be
signed on its behalf by the undersigned, thereunto duly authorized.


                          Southwest Oil & Gas Income Fund X-A, L.P., a
                          Delaware limited partnership


                                        By:    Southwest  Royalties,  Inc.,
                                 Managing
                                 General Partner


                          By:    /s/ H. H. Wommack, III
                                 -----------------------------
                                           H. H. Wommack, III, President


                          Date:  March 31, 2000


Pursuant  to the requirements of the Securities Exchange Act of 1934,  this
report  has  been signed below by the following persons on  behalf  of  the
Partnership and in the capacities and on the dates indicated.


By:    /s/ H. H. Wommack, III
       -----------------------------------
       H. H. Wommack, III, Chairman of the
       Board, President, Chief Executive
       Officer, Treasurer and Director


Date:  March 31, 2000


By:    /s/ H. Allen Corey
       -----------------------------
       H. Allen Corey, Secretary and
       Director


Date:  March 31, 2000

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