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, 1998

                                    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 0-20299

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

Delaware                                                    75-2374445
(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)

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 ___.  There  is  no
exhibit index.

<PAGE>
                            Table of Contents

Item                                                                   Page

                                  Part I

 1.  Business                                                            3

 2.  Properties                                                          7

 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                        21

 9.  Changes in and Disagreements with Accountants
     on Accounting and Financial Disclosure                             38

                                 Part III

10.  Directors and Executive Officers of the Registrant                 39

11.  Executive Compensation                                             42

12.  Security Ownership of Certain Beneficial Owners and
     Management                                                         42

13.  Certain Relationships and Related Transactions                     44

                                 Part IV

14.  Exhibits, Financial Statement Schedules, and Reports
     on Form 8-K                                                        45

     Signatures                                                         46

<PAGE>
                                  Part I

Item 1.   Business

General
Southwest   Oil  &  Gas  Income  Fund  X-C,  L.P.  (the  "Partnership"   or
"Registrant")   was  organized  as  a  Delaware  limited   partnership   on
September  20,  1991.  The offering of limited partnership interests  began
October  1,  1991  as part of a shelf offering registered  under  the  name
Southwest  Oil & Gas 1990-91 Income Program.  Minimum capital  requirements
for  the  Partnership were met on January 13, 1992 and concluded April  30,
1992.  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  98  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 Alabama, Kansas, Louisiana, New Mexico, Oklahoma  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>
During 1998 oil prices fell to their lowest daily levels since 1986 and  to
their lowest annual average since 1976.  In two years, oil prices have been
sliced  by  more  than half.  The factors that started the decline  in  oil
prices in 1997 are the same ones that have kept them down in 1998.  It  was
believed  that there would be continued heavy consumption coming  from  the
Asian  region, but the collapse of their markets late in 1997 carried  over
to  this year bringing demand down with it.  Asian consumption had all  but
disappeared  in  1998, creating an oversupply of crude oil on  the  market.
That  drop  in  demand has lasted longer than anyone had  anticipated,  but
hopes  of  a  recovery abound.  Another reason for the  continued  drop  in
prices  has  been OPEC's unwillingness to completely comply with production
cuts  established in March and again in June.  Although they have been near
90%  compliance at times, they have also been below 70% on a monthly basis.
Even  a  four-day bombing in December of Iraqi military sites could  create
only a one-day rally in oil prices.  Crude oil closed December 31, 1998  at
$12.05  per  barrel  on the NYMEX and posted prices  closed  at  $9.50  per
barrel.

In  a  year  of fairly optimistic expectations for gas prices, the  average
price  of natural gas wound up declining in 1998 to its lowest level  since
1995.   Although the nationwide average did remain above $2.00  per  MMBTU,
1998's  prices were approximately 17% lower than those seen in  1997.   The
combination  of mild weather throughout the year and a gas storage  surplus
both  contributed to the low prices.  Analysts' predictions for 1999 prices
vary,  ranging from a low of $1.87 per MMBTU to a high of $2.40 per  MMBTU.
Reduced  production  throughout the U.S. industry,  along  with  large  gas
storage  withdrawals during the first weeks of January 1999, are  both  key
factors  in  our belief that the 1999 average gas price will remain  around
$1.80 per MMBTU level.

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

                                  Oil          Gas

                    1998          69%          31%
                    1997          72%          28%
                    1996          75%          25%

As  the table indicates, the majority of the Partnership's revenue is  from
its  oil production, and 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
The  Managing  General  Partner intends that 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 66% of the  Partnership's
total  oil and gas production during 1998: Mesa Pipe Line Company for  30%,
Duke  Energy Transport and Trad. for 22% and Hal J Rasmussen Operating Inc.
for  14%.  Two purchasers accounted for 71% of the Partnership's total  oil
and  gas production during 1997: Mesa Pipe Line Company for 55%, and Hal  J
Rasmussen  Operating Inc. for 16%.  Three purchasers accounted for  79%  of
the Partnership's total oil and gas production during 1996:  Mesa Pipe Line
Company  for 57%, Scurlock Permian Corporation for 11% and Hal J. Rasmussen
Operating, Inc. for 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 undue 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,
1998  there  were 98 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.

<PAGE>
As  of December 31, 1998, the Partnership possessed an interest in oil  and
gas  properties located in Escambia and Lamar Counties of Alabama;  Labette
and  Neosho  Counties  of Kansas; La Fourche, Pointe Coupe  and  Terrebonne
Parishes  of  Louisiana;  Chaves, Eddy, and Lea  Counties  of  New  Mexico;
Custer,  Roger  Mills  and  Washita Counties  of  Oklahoma;  and  Colorado,
Dickens,  Gaines, Hemphill, Live Oak, Martin, Mitchell, Scurry,  Upton  and
Yoakum Counties of Texas.  These properties consist of various interests in
430 wells and units.

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 1998, 1997 and 1996.

During 1998, forty-nine leases were sold for approximately $32,400.  During
1997,  one  lease  was sold for approximately $1,700.   During  1996,  five
leases were sold for approximately $225,400.

<PAGE>
Significant Properties
The  following  table  reflects  the  significant  property  in  which  the
Partnership has an interest:

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

Ackerly-Ira-Sharon    10/92 at 4%       407         21,000         58,000
Ridge Acquisition     to 50%
Scurry, Mitchell and  working
Martin Counties,      interest
Texas

Kelt Ohio             1/94 at 25%         1              -        315,000
Acquisition           to 50%
Chaves County,        working
New Mexico            interest

Mettie Poole          10/92 at 26%        1          1,000         98,000
Colorado County,      working
Texas                 interest

*Ryder  Scott Company Petroleum Engineers prepared the reserve and  present
value data for 96.4% of the Partnership's existing properties as of January
1,  1999.   Another independent petroleum engineer prepared  the  remaining
3.6%  of the Partnership's properties.  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, 1998 of $12.05  was
used  as the beginning basis for the oil price.  Oil price adjustments from
$12.05  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 $9.26 per barrel in the preparation of  the
reserve report as of January 1, 1999.

In  the  determination of the gas price, the New York  Mercantile  Exchange
price  at December 31, 1998 of $1.95 was used as the beginning basis.   Gas
price   adjustments  from  $1.95  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 $1.72 per Mcf in the preparation of the reserve report as  of
January 1, 1999.

<PAGE>
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 1998.

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.

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 is conducted pursuant to farmout
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 farmout, 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 1998 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
1998,  38  limited  partner units were tendered to  and  purchased  by  the
Managing General Partner at an average base price of $156.92 per unit.   In
1997,  6  limited  partner  units were tendered to  and  purchased  by  the
Managing General Partner at an average base price of $295.25 per unit.   In
1996,  no  limited  partner units were purchased by  the  Managing  General
Partner.

Number of Limited Partner Interest Holders
As of December 31, 1998, there were 297 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>
During  1998,  distributions  were made totaling  $187,500,  with  $168,750
distributed  to  the limited partners and $18,750 to the general  partners.
For  the  year ended December 31, 1998, distributions of $27.02 per limited
partner unit were made, based upon 6,246 limited partner units outstanding.
The  decline  in  distributions experienced in 1998  will  be  expected  to
continue  into  1999 based on the continued low oil price economy.   During
1997,  twelve  monthly  distributions were  made  totaling  $730,500,  with
$657,450  distributed to the limited partners and $73,050  to  the  general
partners.   For the year ended December 31, 1997, distributions of  $105.26
per  limited partner unit were made, based upon 6,246 limited partner units
outstanding.  During 1996, twelve monthly distributions were made  totaling
$640,452, with $582,702 distributed to the limited partners and $57,750  to
the  general partners.  For the year ended December 31, 1996, distributions
of  $93.29  per  limited partner unit were made, based upon  6,246  limited
partner units outstanding.

Item 6.   Selected Financial Data

The  following  selected financial data for the years  ended  December  31,
1998,  1997,  1996,  1995 and 1994 should be read in conjunction  with  the
financial statements included in Item 8:

                                     Years ended December 31,
                    ---------------------------------------------------------
                         1998        1997        1996      1995      1994
                         ----        ----        ----      ----      ----

Revenues           $    674,143   1,199,005  1,350,355  1,311,128 1,290,119

Net income (loss)     (104,046)     345,547    504,735    270,029   102,660

Partners' share of
 net income (loss):

  General partners        9,295      49,955     62,913     45,351    35,446

  Limited partners    (113,341)     295,592    441,822    224,678    67,214

Limited partners'
 net income (loss)
  per unit              (18.15)       47.33      70.74      35.97      10.76

Limited partners'
 cash distributions
  per unit                27.02      105.26      93.29      70.87     50.15

Total assets       $    478,955     770,617  1,155,545  1,291,318 1,515,431

<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  farmout 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 no workovers
during  1999  to  enhance  production.  With  expected  price  improvement,
workovers may be performed in the year 2000.  The partnership may  have  an
increase  in  the  year 2000, otherwise, the Partnership will  most  likely
experience it's historical decline of approximately 9% per year.


<PAGE>
Results of Operations

A.  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            $   10.90    18.03    (40%)
Average price per mcf of gas               $    2.00     2.58    (22%)
Oil production in barrels                     42,500   47,500    (11%)
Gas production in mcf                        104,900  129,800    (19%)
Gross oil and gas revenue                  $ 672,7171,190,719    (44%)
Net oil and gas revenue                    $ 143,533  535,349    (73%)
Partnership distributions                  $ 187,500  730,500    (74%)
Limited partner distributions              $ 168,750  657,450    (74%)
Per unit distribution to limited partners  $   27.02   105.26    (74%)
Number of limited partner units                6,246    6,246

Revenues

The   Partnership's  oil  and  gas  revenues  decreased  to  $672,717  from
$1,190,719 for the years ended December 31, 1998 and 1997, respectively,  a
decrease  of  44%.  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 40%, or $7.13 per barrel, resulting  in
    a   decrease  of  approximately  $338,700  in  revenues.    Oil   sales
    represented  69%  of  total oil and gas sales  during  the  year  ended
    December 31, 1998 as compared to 72% 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 22%, or $.58 per mcf, resulting  in
    a decrease of approximately $75,300 in revenues.

    The  total  decrease in revenues due to the change in  prices  received
    from  oil  and  gas production is approximately $414,000.   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 5,000 barrels or 11% during the
    year ended December 31, 1998 as compared to the year ended December 31,
    1997, resulting in a decrease of approximately $54,500 in revenues.

    Gas  production  decreased approximately 24,900 mcf or 19%  during  the
    same  period,  resulting  in  a decrease of  approximately  $49,800  in
    revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately  $104,300.   The  decrease  in  gas  production  is   due
    primarily to property sales and natural decline on one well.

Costs and Expenses

Total  costs and expenses decreased to $778,189 from $853,458 for the years
ended  December  31, 1998 and 1997, respectively, a decrease  of  9%.   The
decrease is the result of lower lease operating costs, partially offset  by
an increase in depletion expense and general and administrative expense.

1.    Lease  operating  costs  and production  taxes  were  19%  lower,  or
   approximately $126,200 less during the year ended December 31,  1998  as
   compared to the year ended December 31, 1997.  Decrease due primarily to
   lower advalorem and production taxes and less workovers due to lower oil
   prices.

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
    18% or approximately $7,900 during the year ended December 31, 1998  as
    compared  to the year ended December 31, 1997.  Increase in  accounting
    fees  due  to necessity of contracting out preparation of tax depletion
    and K-1 schedules.

3.  Depletion expense increased to $197,000 for the year ended December 31,
    1998  from  $154,000 for the same period in 1997.  This  represents  an
    increase  of 28%.  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  $40,000  as  of
    December 31, 1997.

<PAGE>

Results of Operations

B.  General Comparison of the Years Ended December 31, 1997 and 1996

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 1997 and 1996:

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                1997      1996   (Decrease)

Average price per barrel of oil            $   18.03    19.53     (8%)
Average price per mcf of gas               $    2.58     2.49       4%
Oil production in barrels                     47,500   51,500     (8%)
Gas production in mcf                        129,800  135,300     (4%)
Gross oil and gas revenue                  $1,190,7191,342,549   (11%)
Net oil and gas revenue                    $ 535,349  666,075    (20%)
Partnership distributions                  $ 730,500  640,452      14%
Limited partner distributions              $ 657,450  582,702      13%
Per unit distribution to limited partners  $  105.26    93.29      13%
Number of limited partner units                6,246    6,246

Revenues

The  Partnership's  oil  and  gas revenues  decreased  to  $1,190,719  from
$1,342,549 for the years ended December 31, 1997 and 1996, respectively,  a
decrease  of  11%.  The principal factors affecting the comparison  of  the
years ended December 31, 1997 and 1996 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the year ended December 31, 1997 as compared  to  the
    year ended December 31, 1996 by 8%, or $1.50 per barrel, resulting in a
    decrease  of  approximately $77,300 in revenues.  Oil sales represented
    72%  of total oil and gas sales during the year ended December 31, 1997
    as compared to 75% during the year ended December 31, 1996.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased  during the same period by 4%, or $.09 per mcf, resulting  in
    an increase of approximately $12,200 in revenues.

    The net total decrease in revenues due to the change in prices received
    from oil and gas production is approximately $65,100.  The market price
    for  oil  and gas has been extremely volatile over the past decade  and
    management  expects a certain amount of volatility to continue  in  the
    foreseeable future.

<PAGE>
2.  Oil  production decreased approximately 4,000 barrels or 8% during  the
    year ended December 31, 1997 as compared to the year ended December 31,
    1996, resulting in a decrease of approximately $72,100 in revenues.

    Gas  production decreased approximately 5,500 mcf or 4% during the same
    period, resulting in a decrease of approximately $14,200 in revenues.

    The  total  decrease  in revenues due to the change  in  production  is
    approximately $86,300.  The decrease is attributable to natural decline
    and the sale of properties in 1996.

Costs and Expenses

Total  costs and expenses increased to $853,458 from $845,620 for the years
ended  December 31, 1997 and 1996, respectively, an increase  of  1%.   The
increase  is  the  result of higher depletion expense partially  offset  by
lease operating costs and general and administrative expense.

2.    Lease  operating  costs  and  production  taxes  were  3%  lower,  or
   approximately $21,100 less during the year ended December  31,  1997  as
   compared to the year ended December 31, 1996.

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 1%
    or  approximately  $700  during the year ended  December  31,  1997  as
    compared to the year ended December 31, 1996.

3.  Depletion expense increased to $154,000 for the year ended December 31,
    1997  from  $118,000 for the same period in 1996.  This  represents  an
    increase  of 31%.  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, 1998 as compared
    to  1997.   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  $31,000  as  of
    December 31, 1996.

<PAGE>

C.  Revenue and Distribution Comparison

Partnership income (loss) for the years ended December 31, 1998,  1997  and
1996  was  $(104,046), $345,547 and $504,735, respectively.  Excluding  the
effects of depreciation, depletion and amortization, net income would  have
been   $92,954   in   1998,  $499,547  in  1997  and  $629,133   in   1996.
Correspondingly, Partnership distributions for the years ended December 31,
1998,  1997  and  1996 were $187,500, $730,500 and $640,452,  respectively.
These  differences  are indicative of the changes in oil  and  gas  prices,
production and property sales.

The  source  for  the  1998  distributions of  $187,500  was  oil  and  gas
operations  of  approximately  $175,300 and  the  change  in  oil  and  gas
properties  of  approximately  $26,100,  resulting  in  excess   cash   for
contingencies  or  subsequent  distributions.   The  source  for  the  1997
distributions  of  $730,500  was oil and gas  operations  of  approximately
$539,600  and  the  change  in  oil  and gas  properties  of  approximately
$(7,800), with the balance from available cash on hand at the beginning  of
the  period.  The sources for the 1996 distributions of $640,452  were  oil
and  gas  operations  of  approximately  $594,400  and  property  sales  of
approximately  $228,000, offset by additions to oil and gas  properties  of
approximately  $8,800,  resulting  in  excess  cash  for  contingencies  or
subsequent distributions.

Total  distributions during the year ended December 31, 1998 were  $187,500
of  which  $168,750 was distributed to the limited partners and $18,750  to
the general partners.  The per unit distribution to limited partners during
the  same  period was $27.02.  Total distributions during  the  year  ended
December  31, 1997 were $730,500 of which $657,450 was distributed  to  the
limited  partners  and  $73,050  to the general  partners.   The  per  unit
distribution to limited partners during the same period was $105.26.  Total
distributions  during  the year ended December 31, 1996  were  $640,452  of
which  $582,702 was distributed to the limited partners and $57,750 to  the
general partners.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $2,923,818  have been made to the partners.  As of December  31,  1998,
$2,648,444 or $424.02 per limited partner unit, has been distributed to the
limited partners, representing a 85% 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 operating activities were approximately $175,260  in
1998 compared to $539,600 in 1997 and approximately $594,400 in 1996.   The
primary  source  of  the  1998  cash flow  from  operating  activities  was
profitable operations.

Cash flows provided by or (used in) investing activities were approximately
$26,100 in 1998 compared to $(7,800) in 1997 and approximately $219,200  in
1996.  The principal source of the 1998 cash flow from investing activities
was sale of oil and gas properties.

Cash flows used in financing activities were approximately $187,700 in 1998
compared to $730,500 in 1997 and approximately $640,500 in 1996.  The  only
1998 use in financing activities was the distributions to partners.

As  of  December  31,  1998, the Partnership has approximately  $80,800  in
working  capital.   The  Managing  General  Partner  believes  the  revenue
generated from operations are adequate to meet the operating needs  of  the
Partnership.

Liquidity - Managing General Partner

The  Managing General Partner has a highly leveraged capital structure with
over   $21.0  million  of  interest  payments  due  in  1999  on  its  debt
obligations.   Due  to  severely depressed commodity prices,  the  Managing
General  Partner  is experiencing difficulty in generating sufficient  cash
flow  to  meet  its obligations and sustain its operations.   The  Managing
General  Partner is currently in the process of renegotiating the terms  of
its  various obligations with its creditors and/or attempting to  seek  new
lenders  or  equity investors.  Additionally, the Managing General  Partner
would   consider  disposing  of  certain  assets  in  order  to  meet   its
obligations.

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

Information Systems for the Year 2000

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

<PAGE>
Identification & Assessment

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

The  proprietary  software of the Partnership is currently  in  process  of
meeting  compliance requirements with an estimated completion date of  mid-
year  1999.   Since this is an internally generated software  package,  the
Managing General Partner has estimated the cost to be approximately $25,000
by  estimating the necessary man-hours.  These modifications are being made
by internal staff and do not represent additional costs to the Partnership.
The  Managing General Partner has not made contingency plans at  this  time
since  the  conversion is ahead of schedule and being handled  by  Managing
General  Partner controlled internal programmers.  Given the complexity  of
the systems being modified, it is anticipated that some problems may arise,
but  with  an expected early completion date, the Managing General  Partner
feels that adequate time is available to overcome unforeseen delays.

DEC has released a fully compliant version of its operating system that  is
used  by  the  Partnership on the DEC VAX system.  It will be installed  in
August 1999, the Managing General Partner believes that this will solve any
potential problems on the system.

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

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

Cost

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

<PAGE>
Risks/Contingency

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

Worst Case Scenario

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



<PAGE>
Item 8.   Financial Statements and Supplementary Data

                      Index to Financial Statements

                                                                       Page

Independent Auditors Reports                                            22

Balance Sheets                                                          24

Statements of Operations                                                25

Statement of Changes in Partners' Equity                                26

Statements of Cash Flows                                                27

Notes to Financial Statements                                           29

<PAGE>









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


We  have  audited the accompanying balance sheets of Southwest  Oil  &  Gas
Income Fund X-C, L.P. (the "Partnership") as of December 31, 1998 and 1997,
and  the related statements of operations, changes in partners' equity  and
cash  flows for the years then ended.  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-C, L.P. as of December 31, 1998 and 1997 and the results  of
its  operations and its cash flows for the years then ended  in  conformity
with generally accepted accounting principles.



                        KPMG LLP



Midland, Texas
March 18, 1999

<PAGE>









                    REPORT OF INDEPENDENT ACCOUNTANTS


To the Partners
Southwest Oil & Gas
 Income Fund X-C, L.P.
Midland, Texas

We  have  audited  the  accompanying statements of operations,  changes  in
partners'  equity  and cash flows of Southwest Oil & Gas Income  Fund  X-C,
L.P. for the year ended December 31, 1996.  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 audit.

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

In  our  opinion, the statements of operations, changes in partners  equity
and  cash flows referred to above present fairly, in all material respects,
the results of operations and cash flows of Southwest Oil & Gas Income Fund
X-C,  L.P.  for  the  year  ended December 31,  1996,  in  conformity  with
generally accepted accounting principles.


                        JOSEPH DECOSIMO AND COMPANY
                           A   Tennessee   Registered   Limited   Liability
Partnership


Chattanooga, Tennessee
March 14, 1997

<PAGE>

                Southwest Oil & Gas Income Fund X-C, L.P.
                     (a Delaware limited partnership)
                              Balance Sheets
                        December 31, 1998 and 1997


                                                      1998           1997
                                                      ----           ----

  Assets

Current assets:
 Cash and cash equivalents                $           22,818        9,123
 Receivable from Managing General Partner             57,902      140,208
 Other receivable                                          -        1,700
 Distribution receivable                                  92            -

---------                                 ---------
                                               Total     current     assets
80,812                                    151,031

---------                                 ---------
Oil and gas properties - using the full-
 cost method of accounting                         2,393,639    2,418,082
  Less accumulated depreciation,
                                             depletion   and   amortization
1,995,496                                 1,798,496

---------                                 ---------
                                            Net   oil  and  gas  properties
398,143                                   619,586

---------                                 ---------
                                                                          $
478,955                                   770,617

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

  Liabilities and Partners' Equity

Current liability - Distribution payable  $                -          116

---------                                 ---------
Partners' equity:
 General partners                                   (15,686)      (6,231)
 Limited partners                                    494,641      776,732

---------                                 ---------
                                              Total     partners'    equity
478,955                                   770,501

---------                                 ---------
                                                                          $
478,955                                   770,617

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




















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

<PAGE>
                Southwest Oil & Gas Income Fund X-C, L.P.
                     (a Delaware limited partnership)
                         Statements of Operations
               Years ended December 31, 1998, 1997 and 1996


                                                 1998      1997     1996
                                                 ----      ----     ----

  Revenues

Oil and gas income                        $    672,717 1,190,7191,342,549
Interest from operations                         1,426     8,286    7,806
                                                                  ---------
---------                                 ---------
                                                                    674,143
1,199,005                                 1,350,355
                                                                  ---------
---------                                 ---------
  Expenses

Production                                     529,184   655,370  676,474
General and administrative                      52,005    44,088   44,748
Depreciation, depletion and amortization       197,000   154,000  124,398
                                                                  ---------
---------                                 ---------
                                                                    778,189
853,458                                   845,620
                                                                  ---------
---------                                 ---------
Net income (loss)                         $  (104,046)   345,547  504,735
                                                                  =========
=========                                 =========
Net income (loss) allocated to:

 Managing General Partner                 $      8,366    44,960   56,622
                                                                  =========
=========                                 =========
 General Partner                          $        929     4,995    6,291
                                                                  =========
=========                                 =========
 Limited partners                         $  (113,341)   295,592  441,822
                                                                  =========
=========                                 =========
  Per limited partner unit                $     (18.15)    47.33    70.74
                                                                  =========
=========                                 =========

























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

<PAGE>
                Southwest Oil & Gas Income Fund X-C, L.P.
                     (a Delaware limited partnership)
                 Statement of Changes in Partners' Equity
               Years ended December 31, 1998, 1997 and 1996


                                              General   Limited
                                              Partners  Partners   Total
                                              --------  --------   -----

Balance at December 31, 1995            $     11,701  1,279,470 1,291,171

 Net income                                   62,913    441,822   504,735

 Distributions                              (57,750)  (582,702) (640,452)
                                                                    -------
---------                               ---------
Balance at December 31, 1996                  16,864  1,138,590 1,155,454

 Net income                                   49,955    295,592   345,547

 Distributions                              (73,050)  (657,450) (730,500)
                                                                    -------
---------                               ---------
Balance at December 31, 1997                 (6,231)    776,732   770,501

 Net income (loss)                             9,295  (113,341) (104,046)

 Distributions                              (18,750)  (168,750) (187,500)
                                                                    -------
---------                               ---------
Balance at December 31, 1998            $   (15,686)    494,641   478,955
                                                                    =======
=========                               =========































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

<PAGE>
                Southwest Oil & Gas Income Fund X-C, L.P.
                     (a Delaware limited partnership)
                         Statements of Cash Flows
               Years ended December 31, 1998, 1997 and 1996


                                                1998       1997     1996
                                                ----       ----     ----

Cash flows from operating
 activities:

 Cash received from oil and gas sales     $    789,961 1,239,5741,302,376
 Cash paid to Managing General Partner
  for administrative fees and general
                                            and   administrative   overhead
(616,127)                                 (708,264)(715,757)
 Interest received                               1,426     8,286    7,806
                                                                  ---------
---------                                 ---------
   Net  cash provided by operating activities              175,260  539,596
594,425
                                                                  ---------
---------                                 ---------
Cash flows from investing activities:

 Purchase of oil and gas properties            (5,991)  (11,838)  (8,802)
 Sale of oil and gas properties                 32,134     4,067  227,978
                                                                  ---------
---------                                 ---------
  Net cash (used in) or provided by investing
                                           activities      26,143   (7,771)
219,176
                                                                  ---------
---------                                 ---------
Cash flows used in financing activities:

 Distributions to partners                   (187,708) (730,475)(640,508)
                                                                  ---------
---------                                 ---------
Net increase (decrease) in cash and cash
 equivalents                                    13,695 (198,650)  173,093

 Beginning of period                             9,123   207,773   34,680
                                                                  ---------
---------                                 ---------
 End of period                            $     22,818     9,123  207,773
                                                                  =========
=========                                 =========


(continued)




















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

<PAGE>
                Southwest Oil & Gas Income Fund X-C, L.P.
                     (a Delaware limited partnership)
                   Statements of Cash Flows, continued
               Years ended December 31, 1998, 1997 and 1996


                                                 1998      1997      1996
                                                 ----      ----      ----

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

Net income (loss)                         $  (104,046)   345,547  504,735

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

   Depreciation, depletion and amortization               197,000   154,000
124,398
  (Increase) decrease in receivables           117,244    48,855 (40,173)
  Increase (decrease) in payables             (34,938)   (8,806)    5,465
                                                                    -------
-------                                   -------
Net cash provided by operating activities $    175,260   539,596  594,425
                                                                    =======
=======                                   =======






































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

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

                      Notes to Financial Statements


1.   Organization
     Southwest Oil & Gas Income Fund X-C, L.P. was organized under the laws
     of  the  state of Delaware on September 20, 1991, 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  several purchasers with the prices it  receives  being
     dependent  upon  the oil and gas economy.  Southwest  Royalties,  Inc.
     serves as the Managing General Partner and H. H.  Wommack, III, as the
     individual   general  partner.   Revenues,  costs  and  expenses   are
     allocated as follows:

                                                     Limited      General
                                                     Partners     Partners
                                                     --------     --------

     Interest income on capital contributions        100%           -
     Oil and gas sales                                90%          10%
     All other revenues                               90%          10%
     Organization and offering costs (1)             100%           -
     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 gas properties                      100%           -
     All other costs                                  90%          10%

          (1)   All  organization costs in excess of 3% of initial  capital
          contributions  will be paid by the Managing General  Partner  and
          will  be treated as a capital contribution.  The Partnership paid
          the  Managing  General Partner an amount equal to 3%  of  initial
          capital contributions for such organization costs.

          (2)   Administrative costs in any year which exceed 2% of capital
          contributions shall be paid by the Managing General  Partner  and
          will be treated as a capital contribution.

<PAGE>
                Southwest Oil & Gas Income Fund X-C, 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, 1998, 1997  and  1996
     the  net capitalized costs did not exceed the estimated present  value
     of the oil and gas reserves.

     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.

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

                      Notes to Financial Statements


2.   Summary of Significant Accounting Policies - continued

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

     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, 1998, there were no
     significant amounts of imbalance in terms of units and value.   As  of
     December 31, 1997 and 1996, the Partnership was over produced by 3,631
     and 3,065 mcf of gas.

     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,  1998  and 1997 is $162,568 and $128,503, 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, 1998 and 1997 there were 6,246  limited  partner
     units outstanding held by 297 partners.  As of December 31, 1996 there
     were 6,246 limited partner units outstanding held by 296 partners.

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

                      Notes to Financial Statements


2.   Summary of Significant Accounting Policies - continued

     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.

3.   Liquidity - Managing General Partner
     The  Managing General Partner has a highly leveraged capital structure
     with  over $21.0 million of interest payments due in 1999 on its  debt
     obligations.  Due to severely depressed commodity prices, 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.

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

                      Notes to Financial Statements


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, 1998, 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-C, 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 $182,000, $173,000 and $176,000, respectively,
     for  the  years ended December 31, 1998, 1997 and 1996.  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
     $4,100,  $100 and $200 for the year ended December 31, 1998, 1997  and
     1996.   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
     $36,000  during  1998,  1997 and 1996, as an administrative  fee,  for
     indirect general and administrative overhead expenses.

     Receivables  from  Southwest  Royalties, Inc.,  the  Managing  General
     Partner,  of approximately $57,902 and $140,208 are from oil  and  gas
     production, net of lease operating costs and production taxes,  as  of
     December 31, 1998 and 1997, 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.  There were no legal services provided for the  year
     ended December 31, 1998, 1997 and approximately $50 for the year ended
     December 31, 1996.

6.   Major Customers
     The  Managing General Partner intends that 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 66% of  the
     Partnership's total oil and gas production during 1998: Mesa Pipe Line
     Company  for 30%, Duke Energy Transport and Trad. for 22%  and  Hal  J
     Rasmussen Operating Inc. for 14%.  Two purchasers accounted for 71% of
     the  Partnership's total oil and gas production during 1997: Mesa Pipe
     Line  Company   55%,  and Hal J Rasmussen Operating  Inc.  16%.  Three
     purchasers  accounted for 79% of the Partnership's total oil  and  gas
     production during 1996:  Mesa Pipe Line Company 57%, Scurlock  Permian
     Corporation  11%  and  Hal  J. Rasmussen  Operating,  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 undue 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-C, 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, 1996                                 299,000     1,305,000

       Sale of minerals in place                    (35,000)      (12,000)
       Revisions of previous estimates                94,000      (50,000)
       Production                                   (51,000)     (135,000)
                                                     -------     ---------
     December 31, 1996                               307,000     1,108,000

       Sale of minerals in place                     (1,000)             -
       Revisions of previous estimates             (131,000)       192,000
       Production                                   (48,000)     (130,000)
                                                     -------     ---------
     December 31, 1997                               127,000     1,170,000

       Sale of minerals in place                     (3,000)     (100,000)
       Revisions of previous estimates              (41,000)     (392,000)
       Production                                   (43,000)     (105,000)
                                                     -------     ---------
     December 31, 1998                                40,000       573,000
                                                     =======     =========

     Proved developed reserves -

     December 31, 1996                               307,000     1,071,000
                                                     =======     =========
     December 31, 1997                               127,000     1,132,000
                                                     =======     =========
     December 31, 1998                                40,000       536,000
                                                     =======     =========

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

     *Ryder  Scott  Company Petroleum Engineers prepared  the  reserve  and
     present  value data for 96.4% of the Partnership's existing properties
     as  of  January  1,  1999.   Another  independent  petroleum  engineer
     prepared  the  remaining  3.6% of the Partnership's  properties.   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, 1998 of $12.05
     was  used  as  the  beginning basis for  the  oil  price.   Oil  price
     adjustments  from  $12.05  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
     $9.26  per  barrel  in  the preparation of the reserve  report  as  of
     January 1, 1999.

<PAGE>

                Southwest Oil & Gas Income Fund X-C, 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, 1998 of $1.95 was used as the beginning
     basis.   Gas  price adjustments from $1.95 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 $1.72 per Mcf  in  the
     preparation of the reserve report as of January 1, 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.  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.

     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 is conducted  pursuant  to
     farmout  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 farmout,
     or receives cash.

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

                      Notes to Financial Statements


7.   Estimated Oil and Gas Reserves (unaudited) - continued
     The  standardized measure of discounted future net cash flows relating
     to  proved oil and gas reserves at December 31, 1998, 1997 and 1996 is
     presented below:

                                             1998       1997         1996
                                             ----       ----         ----

     Future cash inflows                $  1,357,000  4,784,000 11,285,000
     Production and development costs        278,000  2,188,000  5,440,000
                                          ----------  ---------  ---------
     Future net cash flows                 1,079,000  2,596,000  5,845,000
     10% annual discount for estimated
       timing of cash flows                  406,000  1,003,000  2,249,000
                                          ----------  ---------  ---------
     Standardized measure of discounted
       future net cash flows            $    673,000  1,593,000  3,596,000
                                          ==========  =========  =========

     The  principal  sources  of  change in  the  standardized  measure  of
     discounted  future  net cash flows for the years  ended  December  31,
     1998, 1997 and 1996 are as follows:

                                              1998        1997        1996
                                              ----        ----        ----

     Sales of oil and gas produced,
       net of production costs          $  (144,000)  (535,000)(1,087,000)
      Changes in prices and production costs           (339,000)(1,172,000)
2,174,000
     Changes of production rates
       (timing) and others                     8,000  (159,000)  (218,000)
     Revisions of previous
       quantities estimates                (528,000)  (496,000)   (61,000)
     Accretion of discount                   159,000    360,000    362,000
     Sale of minerals in place              (76,000)    (1,000)  (199,000)
     Discounted future net
       cash flows -
      Beginning of year                    1,593,000  3,596,000  2,625,000
                                          ----------  ---------  ---------
      End of year                       $    673,000  1,593,000  3,596,000
                                          ==========  =========  =========

     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.

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

On  June  9,  1997  Southwest  Royalties, Inc. the  Partnership's  Managing
General  Partner (Southwest Royalties, Inc.) dismissed Joseph Decosimo  and
Company as the Partnership's independent accountants.  The Managing General
Partner's   Board  of  Directors  approved  the  decision  to  change   the
Partnership's independent accountants.

The  report of Joseph Decosimo and Company on the financial statements  for
the  fiscal  year ended December 31, 1996 contained no adverse  opinion  or
disclaimer  of opinion and was not qualified or modified as to uncertainty,
audit scope or accounting principle.

In  connection with its audit for the fiscal year ended December  31,  1996
and  through  June  9, 1997, there have been no disagreements  with  Joseph
Decosimo  and Company on any matter of accounting principles or  practices,
financial  statements  disclosure, or auditing scope  or  procedure,  which
disagreements  if not resolved to the satisfaction of Joseph  Decosimo  and
Company would have caused them to make reference thereto in their report on
the financial statements for such year.

The  Registrant has requested that Joseph Decosimo and Company  furnish  it
with  a  letter addressed to the SEC stating whether or not is agrees  with
the  above statements.  A copy of that letter is included as Exhibit 16 and
has been filed with the Securities and Exchange Commission.


          

<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                      43     Chairman   of   the   Board,
                                        President,
                                        Chief Executive Officer, Treasurer
                                        and Director

H. Allen Corey              42          Secretary and Director

Bill E. Coggin                          44     Vice  President  and   Chief
                                        Financial Officer

Jon P. Tate                             41     Vice  President,  Land   and
                                        Assistant Secretary

R. Douglas Keathley         43          Vice President, Operations

J. Steven Person            40          Vice President, Marketing

Paul L. Morris              57          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.

<PAGE>
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.

Jon  P.  Tate,  Vice President, Land and Assistant Secretary,  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,   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.

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

Accounting  and Administrative Officer - Debbie A. Brock, age  46,  assumed
her  position with the Managing General Partner in 1991.  Prior to  joining
the Managing General Partner, Ms. Brock was employed with Western Container
Corporation   as  Accounting  Manager  (1982-1990),  Synthetic   Industries
(Texas), Inc. as Accounting Manager (1976-1982) and held various accounting
positions in the manufacturing industry (1971-1975).  Ms. Brock received  a
B.B.A. from the University of Houston.

Controller - Robert A. Langford, age 49, assumed his responsibilities  with
the  Managing  General Partner in 1992.  Mr. Langford received  his  B.B.A.
degree  in  Accounting  in 1975 from the University  of  Central  Arkansas.
Prior  to  joining the Managing General Partner,  Mr. Langford was employed
with Forest Oil Corporation as Corporate Coordinator, Regional Coordinator,
Accounting  Manager.  He held various other positions  from  1982-1992  and
1976-1980  and was Assistant Controller of National Oil Company from  1980-
1982.

Financial  Reporting  Manager - Bryan Dixon, C.P.A., age  32,  assumed  his
responsibilities  with the Managing General Partner  in  1992.   Mr.  Dixon
received his B.B.A. degree in Accounting in 1988 from Texas Tech University
in  Lubbock,  Texas.   Prior to joining the Managing General  Partner,  Mr.
Dixon was employed as a Senior Auditor with Johnson, Miller & Company  from
1991-1992 and Audit Supervisor for Texas Tech University and the Texas Tech
University Health Sciences Center from 1988-1991.

Production   Superintendent  -  Steve  C.  Garner,  age  57,  assumed   his
responsibilities   with   the  Managing  General  Partner   as   Production
Superintendent  in  July,  1989.  Prior to  joining  the  Managing  General
Partner,  Mr. Garner was employed 16 years by Shell Oil Company working  in
all  phases of oil field production as operations foreman, one and one-half
years  with Petroleum Corporation of Delaware as Production Superintendent,
six  years  as  an independent engineering consultant, and  one  year  with
Citation  Oil & Gas Corp. as a workover, completion and production foreman.
Mr.  Garner has worked extensively in the Permian Basin oil field  for  the
last 25 years.

Tax  Manager  -  Carolyn  Cookson, age 42, assumed her  position  with  the
Managing  General  Partner in April, 1989.  Prior to joining  the  Managing
General  Partner,  Ms. Cookson was employed as Director of  Taxes  at  C.F.
Lawrence  &  Associates,  Inc. from 1983 to  1989,  and  worked  in  public
accounting  at McCleskey, Cook & Green, P.C. from 1981 to 1983  and  Deanna
Brady,  C.P.A.  from 1980 to 1981.  She is a member of  the  Permian  Basin
Chapter  of the Petroleum Accountants' Society, and serves on its Board  of
Directors  and  is  liaison to the Tax Committee.  Ms. Cookson  received  a
B.B.A. in accounting from New Mexico State University.


<PAGE>
Investor  Relations Manager - Sandra K. Flournoy, age 52, came to Southwest
Royalties,  Inc.  in 1988 from Parker & Parsley Petroleum,  where  she  was
Assistant Manager of Investor Services and Broker/Dealer Relations for  two
years.   Prior  to that, Ms. Flournoy was Administrative Assistant  to  the
Superintendent at Greenwood ISD for four years.

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  Partner
received  $36,000  during 1998, 1997 and 1996 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  in  the
Partnership  as a general partner.  Through repurchases of limited  partner
units,  the Managing General Partner also owns 88 limited partner units,  a
1.4%   limited  partner  interest.   The  Managing  General  Partner  total
percentage interest ownership in the Partnership is 10.2%.

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 in the Partnership 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    1.4%
 Interest            Managing General Partner     88 Units
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  H. H. Wommack, III           Indirectly Owns  1.4%
 Interest            Chairman of the Board,       88 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  1.4%
 Interest            Secretary and Director of    88 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     633 Chestnut Street
                     Chattanooga, TN  37450-1800

Limited Partnership  Bill E. Coggin               Indirectly Owns  1.4%
 Interest            Vice President and CFO of    88 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  Jon P. Tate                  Indirectly Owns  1.4%
 Interest            Vice President, Land and     88 Units
                     Assistant Secretary of
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  J. Steven Person             Indirectly Owns  1.4%
 Interest            Vice President, Marketing    88 Units
                     of Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

<PAGE>
                                                   Amount and
                                                   Nature of      Percent
                      Name and Address of          Beneficial        of
 Title of Class         Beneficial Owner           Ownership       Class
-------------------  ---------------------------  ---------------  -------
Limited Partnership  R. Douglas Keathley          Indirectly Owns  1.4%
 Interest            Vice President, Operations   88 Units
                     of Southwest Royalties, Inc.,
                     the Managing General Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  Paul L. Morris               Indirectly Owns  1.4%
 Interest            Director of Southwest,       88 Units
                     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.

Item 13.  Certain Relationships and Related Transactions

In 1998, the Managing General Partner received $36,000 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 $182,000 for administrative  overhead
attributable to operating such properties during 1998.

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 $4,100 for the year ended
December 31, 1998.

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 --

                  Reports of Independent Accountants
                  Balance Sheets
                  Statement of Operations
                  Statement of Changes in Partners' Equity
                  Statement 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-
                          C,  L.P., dated September 20, 1991. (Incorporated
                          by reference from Partnership's Form 10-K for the
                          fiscal year ended December 31, 1991.)

                                            (b)    Agreement   of   Limited
                          Partnership of Southwest Oil & Gas Income Fund X-
                          C,  L.P.  dated September 20, 1991. (Incorporated
                          by reference from Partnership's Form 10-K for the
                          fiscal year ended December 31, 1991.)

                  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, 1998.

<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-C, 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, 1999


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, 1999


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


Date:  March 31, 1999

<PAGE>