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                                FORM 10-Q


                    SECURITIES AND EXCHANGE COMMISSION
                         WASHINGTON, D.C.  20549

(MARK ONE)

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

For the quarterly period ended March 31, 2002

                                    OR

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

For the transition period from ________________ to ________________

Commission File Number 0-20298

         SOUTHWEST ROYALTIES INSTITUTIONAL 1990-91 INCOME PROGRAM
         Southwest Royalties Institutional Income Fund X-C, L.P.
                  (Exact name of registrant as specified
                  in its limited partnership agreement)

Delaware                                75-2374449
(State or other jurisdiction of                (I.R.S. Employer
incorporation or organization)                Identification No.)


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

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

Indicate  by  check  mark  whether registrant (1)  has  filed  all  reports
required to be filed by Section 13 or 15(d) of the Securities Exchange  Act
of 1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject  to
such filing requirements for the past 90 days:

                            Yes   X   No

        The total number of pages contained in this report is 14.

<PAGE>
                     PART I. - FINANCIAL INFORMATION


Item 1.   Financial Statements

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

<PAGE>
         Southwest Royalties Institutional Income Fund X-C, L.P.

                              Balance Sheets


                                                 March 31,     December 31,
                                                    2002           2001
                                                 ---------     ------------
                                                (unaudited)

  Assets
  ------

Current assets:
 Cash and cash equivalents                   $        12,288       15,300
 Receivable from Managing General Partner             16,170       35,973

---------                                    ---------
                                                 Total    current    assets
28,458                                       51,273

---------                                    ---------
Oil and gas properties - using the full-
  method of accounting                             2,221,662    2,221,662
                                             Less accumulated depreciation,
                                               depletion  and  amortization
2,073,479                                    2,066,479

---------                                    ---------
                                              Net  oil  and gas  properties
148,183                                      155,183

---------                                    ---------
                                                                          $
176,641                                      206,456

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

Partners' equity:
 General partners                            $      (29,204)     (26,923)
 Limited partners                                    205,845      233,379

---------                                    ---------
                                                Total    partners'   equity
176,641                                      206,456

---------                                    ---------
                                                                          $
176,641                                      206,456

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

<PAGE>
         Southwest Royalties Institutional Income Fund X-C, L.P.

                         Statements of Operations
                               (unaudited)


                                                        Three Months Ended
                                                            March 31,
                                                          2002      2001
                                                          ----      ----

  Revenues
  --------

Income from net profits interests                   $  (12,714)    122,285
Interest                                                     34      1,104
                                                        -------    -------
                                                       (12,680)    123,389
                                                        -------    -------
  Expenses
  --------

General and administrative                               10,135     10,053
Depreciation, depletion and amortization                  7,000     14,000
                                                        -------    -------
                                                         17,135     24,053
                                                        -------    -------
Net (loss) income                                   $  (29,815)     99,336
                                                        =======    =======
Net (loss) income allocated to:

 Managing General Partner                           $   (2,053)     10,200
                                                        =======    =======
 General partner                                    $     (228)      1,133
                                                        =======    =======
 Limited partners                                   $  (27,534)     88,003
                                                        =======    =======
  Per limited partner unit                          $    (4.60)     14.71
                                                        =======    =======

<PAGE>
         Southwest Royalties Institutional Income Fund X-C, L.P.

                         Statements of Cash Flows
                               (unaudited)


                                                        Three Months Ended
                                                            March 31,
                                                          2002      2001
                                                          ----      ----
Cash flows from operating activities:

 Cash received from net profits interest            $     6,330    124,838
 Cash paid to suppliers                                 (9,376)    (9,965)
 Interest received                                           34      1,104
                                                       --------   --------
   Net cash (used in) provided by operating activities              (3,012)
115,977
                                                       --------   --------
Cash flows used in financing activities:

 Distributions to partners                                    -  (120,000)
                                                       --------   --------
Net decrease in cash and cash equivalents               (3,012)    (4,023)

 Beginning of period                                     15,300     87,960
                                                       --------   --------
 End of period                                      $    12,288     83,937
                                                       ========   ========

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

Net (loss) income                                   $  (29,815)     99,336

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

  Depreciation, depletion and amortization                7,000     14,000
  Decrease in receivables                                19,044      2,553
  Increase in payables                                      759         88
                                                        -------    -------
Net cash (used in) provided by operating activities $   (3,012)    115,977
                                                        =======    =======

<PAGE>
         Southwest Royalties Institutional Income Fund X-C, L.P.
                     (a Delaware limited partnership)

                      Notes to Financial Statements


1.   Organization
     Southwest  Royalties Institutional 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.

2.   Summary of Significant Accounting Policies
     The  interim financial information as of March 31, 2002, and  for  the
     three  months ended March 31, 2002, is unaudited.  Certain information
     and  footnote  disclosures normally included in  financial  statements
     prepared  in accordance with generally accepted accounting  principles
     have been condensed or omitted in this Form 10-Q pursuant to the rules
     and  regulations of the Securities and Exchange Commission.   However,
     in  the  opinion  of  management, these interim  financial  statements
     include all the necessary adjustments to fairly present the results of
     the interim periods and all such adjustments are of a normal recurring
     nature.  The interim consolidated financial statements should be  read
     in  conjunction  with the audited financial statements  for  the  year
     ended December 31, 2001.

<PAGE>
Item 2.   Management's  Discussion and Analysis of Financial Condition  and
          Results of Operations

General

Southwest Royalties Institutional Income Fund X-C, L.P. was organized as  a
Delaware limited partnership on September 20, 1991.  The offering  of  such
limited  partnership interests began October 1, 1991 as  part  of  a  shelf
offering registered under the name Southwest Royalties Institutional  1990-
91  Income Program.  Minimum capital requirements for the Partnership  were
met on January 28, 1992, with the offering of limited partnership interests
concluding April 30, 1992.

The Partnership was formed to acquire royalty and net profits interests  in
producing  oil  and  gas properties, to produce and market  crude  oil  and
natural  gas  produced  from such properties, and  to  distribute  the  net
proceeds from operations to the limited and general partners.  Net revenues
from  producing  oil  and gas properties will not be  reinvested  in  other
revenue  producing  assets except to the extent that production  facilities
and wells are improved or reworked or where methods are employed to improve
or enable more efficient recovery of oil and gas reserves.

Increases   or   decreases   in  Partnership   revenues   and,   therefore,
distributions  to partners will depend primarily on changes in  the  prices
received  for  production,  changes in volumes of  production  sold,  lease
operating  expenses, enhanced recovery projects, offset drilling activities
pursuant  to farm-out arrangements, sales of properties, and the  depletion
of  wells.   Since  wells deplete over time, production  can  generally  be
expected to decline from year to year.

Well  operating costs and general and administrative costs usually decrease
with   production   declines;  however,  these  costs  may   not   decrease
proportionately.  Net income available for distribution to the partners  is
therefore expected to fluctuate in later years based on these factors.

Based on current conditions, management anticipates performing no workovers
during  2002  to  enhance  production.  The partnership  will  most  likely
experience the historical production decline of approximately 9% per year.

Oil and Gas Properties

Oil  and  gas  properties  are accounted for at cost  under  the  full-cost
method.  Under this method, all productive and nonproductive costs incurred
in  connection with the acquisition, exploration and development of oil and
gas  reserves  are capitalized.  Gain or loss on the sale of  oil  and  gas
properties  is not recognized unless significant oil and gas  reserves  are
involved.

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

Should the net capitalized costs exceed the estimated present value of  oil
and gas reserves, discounted at 10%, such excess costs would be charged  to
current  expense.  As of March 31, 2002, the net capitalized costs did  not
exceed the estimated present value of 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.

<PAGE>
The  Partnership's  interest  in oil and gas  properties  consists  of  net
profits  interests  in  proved properties located  within  the  continental
United  States.   A net profits interest is created when  the  owner  of  a
working  interest in a property enters into an arrangement  providing  that
the  net profits interest owner will receive a stated percentage of the net
profit  from  the  property.   The  net profits  interest  owner  will  not
otherwise participate in additional costs and expenses of the property.

The  Partnership recognizes income from its net profits interest in oil and
gas property on an accrual basis, while the quarterly cash distributions of
the net profits interest are based on a calculation of actual cash received
from  oil  and  gas sales, net of expenses incurred during  that  quarterly
period.  The  net  profits interest is a calculated revenue  interest  that
burdens  the  underlying  working interest in the  property,  and  the  net
profits  interest  owner is not responsible for the actual  development  or
production  expenses  incurred.  Accordingly, if the net  profits  interest
calculation results in expenses incurred exceeding the oil and  gas  income
received during a quarter, no cash distribution is due to the Partnership's
net  profits  interest  until  the deficit is  recovered  from  future  net
profits.   The  Partnership accrues a quarterly loss  on  its  net  profits
interest provided there is a cumulative net amount due for accrued  revenue
as of the balance sheet date.

Critical Accounting Policies

Full cost ceiling calculations The Partnership follows the full cost method
of  accounting  for  its  oil and gas properties.   The  full  cost  method
subjects  companies to quarterly calculations of a "ceiling", or limitation
on  the  amount of properties that can be capitalized on the balance sheet.
If  the  Partnership's capitalized costs are in excess  of  the  calculated
ceiling, the excess must be written off as an expense.

The  Partnership's discounted present value of its proved oil  and  natural
gas  reserves  is  a  major  component  of  the  ceiling  calculation,  and
represents  the  component  that requires the  most  subjective  judgments.
Estimates  of  reserves are forecasts based on engineering data,  projected
future  rates  of  production and the timing of future  expenditures.   The
process  of  estimating oil and natural gas reserves  requires  substantial
judgment,  resulting  in  imprecise determinations,  particularly  for  new
discoveries.   Different reserve engineers may make different estimates  of
reserve  quantities  based  on the same data.   The  Partnership's  reserve
estimates are prepared by outside consultants.

The  passage  of  time  provides  more  qualitative  information  regarding
estimates of reserves, and revisions are made to prior estimates to reflect
updated  information.   However,  there  can  be  no  assurance  that  more
significant  revisions  will not be necessary in  the  future.   If  future
significant  revisions  are  necessary  that  reduce  previously  estimated
reserve quantities, it could result in a full cost property writedown.   In
addition to the impact of these estimates of proved reserves on calculation
of  the  ceiling,  estimates  of proved reserves  are  also  a  significant
component of the calculation of DD&A.

While  the quantities of proved reserves require substantial judgment,  the
associated prices of oil and natural gas reserves that are included in  the
discounted  present  value of the reserves do not  require  judgment.   The
ceiling calculation dictates that prices and costs in effect as of the last
day  of  the  period are generally held constant indefinitely. Because  the
ceiling  calculation dictates that prices in effect as of the last  day  of
the  applicable quarter are held constant indefinitely, the resulting value
is  not indicative of the true fair value of the reserves.  Oil and natural
gas  prices have historically been cyclical and, on any particular  day  at
the  end of a quarter, can be either substantially higher or lower than the
Partnership's  long-term price forecast that is a barometer for  true  fair
value.

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

<PAGE>
Results of Operations

A.  General Comparison of the Quarters Ended March 31, 2002 and 2001

The  following  table  provides certain information  regarding  performance
factors for the quarters ended March 31, 2002 and 2001.

                                               Three Months
                                                  Ended         Percentage
                                                March 31,        Increase
                                              2002      2001    (Decrease)
                                              ----      ----    ----------
Average price per barrel of oil           $   16.68     25.27    (34%)
Average price per mcf of gas              $    1.96      6.75    (71%)
Oil production in barrels                     6,800     7,000     (3%)
Gas production in mcf                         8,500    11,600    (27%)
Income from net profits interests         $(12,714)   122,285   (110%)
Partnership distributions                 $       -   120,000   (100%)
Limited partner distributions             $       -   108,000   (100%)
Per unit distribution to limited
 partners                                 $       -     18.05   (100%)
Number of limited partner units               5,983     5,983

Revenues

The  Partnership's income from net profits interests decreased to $(12,714)
from $122,285 for the quarters ended March 31, 2002 and 2001, respectively,
a  decrease of 110%. The principal factors affecting the comparison of  the
quarters ended March 31, 2002 and 2001 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the quarter ended March 31, 2002 as compared  to  the
    quarter ended March 31, 2001 by 34%, or $8.59 per barrel, resulting  in
    a  decrease  of  approximately  $58,400  in  income  from  net  profits
    interests.  Oil sales represented 87% of total oil and gas sales during
    the  quarter ended March 31, 2002 as compared to 69% during the quarter
    ended March 31, 2001.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 71%, or $4.79 per mcf, resulting in
    a  decrease  of  approximately  $40,700  in  income  from  net  profits
    interests.

    The  total  decrease in income from net profits interests  due  to  the
    change  in prices received from oil and gas production is approximately
    $99,100.   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 200 barrels or  3%  during  the
    quarter ended March 31, 2002 as compared to the quarter ended March 31,
    2001,  resulting in a decrease of approximately $5,100 in  income  from
    net profits interests.

    Gas production decreased approximately 3,100 mcf or 27% during the same
    period, resulting in a decrease of approximately $20,900 in income from
    net profits interests.

    The  total  decrease in income from net profits interests  due  to  the
    change in production is approximately $26,000.  Gas production is  down
    primarily  due  to downtime on one lease in addition to a  non-operated
    lease having a steep natural decline.

3.  Lease  operating  costs  and  production  taxes  were  7%  higher,   or
    approximately $9,900 more during the quarter ended March  31,  2002  as
    compared to the quarter ended March 31, 2001.

Costs and Expenses

Total costs and expenses decreased to $17,135 from $24,053 for the quarters
ended  March  31,  2002  and 2001, respectively, a decrease  of  29%.   The
decrease is the result of lower depletion expense, partially offset  by  an
increase in general and administrative expense.

1.  General and administrative costs consists of independent accounting and
    engineering  fees,  computer services, postage,  and  Managing  General
    Partner personnel costs.  General and administrative costs increased 1%
    or  approximately  $100  during the quarter ended  March  31,  2002  as
    compared to the quarter ended March 31, 2001.

2.  Depletion  expense decreased to $7,000 for the quarter ended March  31,
    2002  from  $14,000  for the same period in 2001.   This  represents  a
    decrease  of 50%.  Depletion is calculated using the units  of  revenue
    method  of  amortization based on a percentage of current period  gross
    revenues  to  total future gross oil and gas revenues, as estimated  by
    the  Partnership's  independent  petroleum  consultants.   Contributing
    factors  to  the decrease in depletion expense between the  comparative
    periods  were  the decrease in the price of gas used to  determine  the
    Partnership's reserves for April 1, 2002 as compared to 2001,  and  the
    decrease  in  oil  and gas revenues received by the Partnership  during
    2002 as compared to 2001.

<PAGE>
Liquidity and Capital Resources

The  primary source of cash is from operations, the receipt of income  from
interests in oil and gas properties.  The Partnership knows of no  material
change, nor does it anticipate any such change.

Cash  flows  (used in) provided by operating activities were  approximately
$(3,000)  in  the quarter ended March 31, 2002 as compared to approximately
$116,000 in the quarter ended March 31, 2001.

There  were no cash flows used in financing activities in the quarter ended
March  31, 2002. Cash flows used in financing activities were approximately
$120,000 in the quarter ended March 31, 2001.

There were no distributions during the quarter ended March 31, 2002.  Total
distributions  during  the quarter ended March 31, 2001  were  $120,000  of
which  $108,000 was distributed to the limited partners and $12,000 to  the
general partners.  The per unit distribution to limited partners during the
quarter ended March 31, 2001 was $18.05.

The primary sources for the 2001 distributions of $120,000 were oil and gas
operations of approximately $116,000, with the balance from available  cash
on hand at the beginning of the period.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $3,263,882  have  been made to the partners.  As  of  March  31,  2002,
$2,950,978 or $493.23 per limited partner unit has been distributed to  the
limited partners, representing a 99% return of the capital contributed.

As  of March 31, 2002, the Partnership had approximately $28,500 in working
capital.   The  Managing  General Partner knows of no  unusual  contractual
commitments  and  believes  the  revenues  generated  from  operations  are
adequate to meet the needs of the Partnership.

Liquidity - MD&A

The  Partnership accrued an oil and gas revenue receivable (included in the
receivable from the Managing General Partner) of $47,162 at March 31, 2002,
and  recognized a net loss in the first quarter of 2002 on an accrual basis
for  its net profits interest in oil and gas properties. Cash distributions
of  the  net  profits interest are based on actual cash received  from  the
underlying  oil  and gas properties, net of expenses incurred  during  that
quarterly  period.  Accordingly, if the net  profits  interest  calculation
results  in  expenses  incurred exceeding the oil and gas  income  received
during  a  quarter  no  net  cash is due to the Partnership's  net  profits
interest  until  the deficit is recovered from future net  profits.  Future
cash distributions to the Partnership are dependent on a positive quarterly
net  profits  calculation on the underlying properties, which differs  from
the calculation on an accrual basis.

<PAGE>
Liquidity - Managing General Partner

The  Managing General Partner has a highly leveraged capital structure with
$50.0  million and $123.7 million of principal due in August  of  2003  and
October  of  2004, respectively.  The Managing General Partner  will  incur
approximately  $17.6  million in interest payments  in  2002  on  its  debt
obligations. Due to the depressed commodity prices experienced  during  the
last  quarter  of  2001,  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.   Upon  the
occurrence of any event of dissolution by the Managing General Partner, the
holders  of  a  majority of limited partnership interests may,  by  written
agreement,  elect  to  continue the business  of  the  Partnership  in  the
Partnership's   name,  with  Partnership  property,  in   a   reconstituted
partnership under the terms of the partnership agreement and to designate a
successor  Managing General Partner.  The Managing General  Partner  as  of
April  19, 2002, successfully completed an exchange of a portion  of  their
bond  debt  for equity and performed a refinancing of its revolving  credit
facility.

Recent Accounting Pronouncements

The  FASB  has  issued Statement No. 143 "Accounting for  Asset  Retirement
Obligations" which establishes requirements for the accounting of  removal-
type  costs  associated with asset retirements.  The standard is  effective
for  fiscal  years beginning after June 15, 2002, with earlier  application
encouraged.  The Managing General Partner is currently assessing the impact
on the partnerships financial statements.

On  October 3, 2001, the FASB issued Statement No. 144 "Accounting for  the
Impairment   or   Disposal  of  Long-Lived  Assets."   This   pronouncement
supercedes FAS 121 "Accounting for the Impairment of Long-Lived Assets  and
for  Long-Lived  Assets to Be Disposed" and eliminates the  requirement  of
Statement  121 to allocate goodwill to long-lived assets to be  tested  for
impairment.   The provisions of this statement are effective for  financial
statements issued for fiscal years beginning after December 15,  2001,  and
interim  periods  within those fiscal years.  Assessment  by  the  Managing
General  Partner  revealed this pronouncement to  have  no  impact  on  the
partnerships.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk

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

<PAGE>
                       PART II. - OTHER INFORMATION


Item 1.   Legal Proceedings

          None

Item 2.   Changes in Securities

          None

Item 3.   Defaults Upon Senior Securities

          None

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

          None

Item 5.   Other Information

          None

Item 6.   Exhibits and Reports on Form 8-K

               (a)  Report on Form 8-K:

                     No  reports on Form 8-K were filed during the  quarter
               for which this report is filed.

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                                SIGNATURES


Pursuant  to the requirements of the Securities Exchange Act of  1934,  the
registrant  has duly caused this report to be signed on its behalf  by  the
undersigned thereunto duly authorized.


                              SOUTHWEST ROYALTIES INSTITUTIONAL
                              INCOME FUND X-C, L.P.
                              a Delaware limited partnership


                              By:  Southwest Royalties, Inc.
                                   Managing General Partner


                              By:  /s/ Bill E. Coggin
                                   ------------------------------
                                   Bill E. Coggin, Vice President
                                   and Chief Financial Officer



Date:  May 15, 2002

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