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, 2001

                                    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 0-15411

                 Southwest Royalties, Inc. Income Fund VI
                (Exact name of registrant as specified in
                    its limited partnership agreement)

Tennessee                                                   75-2127812
(State or other jurisdiction                             (I.R.S. Employer
of incorporation or organization)                       Identification No.)

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

Registrant's telephone number, including area (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  52.   The  exhibit
index is found on page 46.

<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 the 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                       20

 9.   Changes in and Disagreements with Accountants
      on Accounting and Financial Disclosure                            36

                                 Part III

10.   Directors and Executive Officers of the Registrant                37

11.   Executive Compensation                                            39

12.   Security Ownership of Certain Beneficial Owners
      and Management                                                    39

13.   Certain Relationships and Related Transactions                    41

                                 Part IV

14.   Exhibits, Financial Statement Schedules and Reports
      on Form 8-K                                                       42

      Signatures                                                        46

<PAGE>

                                  Part I


Item 1.   Business

General
Southwest   Royalties,   Inc.  Income  Fund  VI   (the   "Partnership"   or
"Registrant") was organized as a Tennessee limited partnership on  December
4,  1986.   The offering of limited partnership interests began August  25,
1986, reached minimum capital requirements on October 3, 1986 and concluded
January 29, 1987.  The Partnership has no subsidiaries.

The  Partnership  has  expended  its  capital  and  acquired  interests  in
producing oil and gas properties.  After such acquisitions, the Partnership
has  produced and marketed the crude oil and natural gas produced from such
properties.  In most cases, the Partnership purchased royalty or overriding
royalty interests and working interests in oil and gas properties that were
converted  into net profits interests or other nonoperating interests.  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  89  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.  Effective  December
31,  2001,  Mr. Wommack sold his general partner interest to  the  Managing
General Partner.  The Partnership has no employees.

Principal Products, Marketing and Distribution
The  Partnership has acquired and holds royalty interests  and  net  profit
interests  in  oil and gas properties located in Texas, Illinois,  Colorado
and  Oklahoma.  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 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>

For  nearly nine months, despite the fears of a global recession, crude oil
prices  held steady between $26 and $28 per barrel due in part to a  series
of  OPEC  and  non-OPEC production cuts.  Then, following what  has  become
known  simply  as  "9-11",  crude prices plunged  immediately  to  $22  and
gradually  fell  to below $18 per barrel.  Slower demand  across  the  U.S.
caused by the threat of recession and warmer than expected weather also led
to  declining prices in the latter half of 2001.  However, the  oil  cartel
and other non-member countries agreed for the fourth time since February to
curb  output in an effort to stabilize prices.  Crude oil contracts trading
on the NYMEX closed the year at approximately $20 per barrel.

Spot  prices in 2001 climbed to their highest levels ever, with the  yearly
average  price  nationwide reaching $4.14/MMBtu, up  9.77%  from  the  2000
average  of $3.77/MMBtu.  Prices reached their zenith in the first  quarter
of  2001 before beginning a steady decline throughout the remainder of  the
year.   The  terrorist  attacks  of  September  11  knocked  the  New  York
Mercantile Exchange out of the market for several days and shook  the  spot
marketplace into a maintenance mode.  As companies measured the  impact  of
the  attacks on the U.S. economy, spot prices deteriorated further.  In the
fourth  quarter,  prices  bottomed out for the year  with  the  three-month
average  falling to $2.31/MMBtu.  As for 2002, record-high  storage  levels
and  the  expectation of a flat economy through the first half of the  year
are  leading  industry  experts to predict prices to  average  $2.05/MMBtu,
remaining above the $2.00 per MMBtu level for a 5th consecutive year.

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

                                 Oil        Gas
                    2001         32%        68%
                    2000         39%        61%
                    1999         44%        56%

As the table indicates, the Partnership's revenue are greater from gas than
oil  production, the Partnership revenues will be highly dependent upon the
future prices and demands for oil and gas.

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

<PAGE>

Customer Dependence
No  material portion of the Partnership's business is dependent on a single
purchaser,  or a very few purchasers, where the loss of one  would  have  a
material  adverse impact on the Partnership. Two purchasers  accounted  for
68%  of  the Partnership's total oil and gas production during 2001:   Duke
Energy  Field  Services  for  55% and Plains Marketing  LP  for  13%.   Two
purchasers  accounted  for  59%  of the Partnership's  total  oil  and  gas
production  during  2000:  Phillips 66 Natural Gas Co. for  48%  and  Plain
Marketing,  LP  for  11%.  Three  purchasers  accounted  for  64%  of   the
Partnership's  total  oil  and gas production  during  1999:   Phillips  66
Natural Gas Co. for 42%, Scurlock Permian LLC for 11% and Genesis Crude Oil
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 net profits or royalty 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,
2001,  there were 89 individuals directly employed by the Managing  General
Partner in various capacities.

<PAGE>

Item 2.  Properties

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

As  of December 31, 2001, the Partnership possessed an interest in oil  and
gas  properties located in Jackson and Weld Counties of Colorado;  Clinton,
Lawrence  and Marion Counties of Illinois; Alfalfa, Beaver, Ellis,  Garvin,
Haskell,  Latimer,  Leflore,  Logan, McClain,  Noble,  Pottawatomie,  Roger
Mills,  Seminole  and Woods Counties of Oklahoma; Brazos,  Burleson,  Coke,
Eastland,  Ector,  Fayette,  Gaines, Jim Wells,  Lee,  Lipscomb,  Mitchell,
Nolan,  Pecos, Reeves, Runnels, Sterling, Upton, Ward and Winkler  Counties
of  Texas.   These properties consist of various interests in approximately
158 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 has not been any
significant changes in properties during 2001, 2000 and 1999.

There were no leases sold during 2001.  During 2000, five leases were  sold
for approximately $2,500.  There were no leases sold during 1999.

<PAGE>

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

                        Date
                     Purchased           No. of         Proved Reserves*
Name and Location   and Interest         Wells        Oil (bbls) Gas (mcf)
-----------------   ------------         ------       ---------- ---------
Mobil Amacker         7/87 at 23%          10           17,000  4,747,000
Tippet                to 100% net
Upton County,         profits
Texas                 interests

*Ryder  Scott  Petroleum Engineers prepared the reserve and  present  value
data for the Partnership's existing properties as of January 1, 2002.   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.

Oil  price  adjustments were made in the individual evaluations to  reflect
oil  quality,  gathering  and transportation costs.   The  results  of  the
reserve  report as of January 1, 2002 are an average price  of  $18.50  per
barrel.

Gas  price  adjustments were made in the individual evaluations to  reflect
BTU  content,  gathering and transportation costs and  gas  processing  and
shrinkage.  The results of the reserve report as of January 1, 2002 are  an
average price of $2.14 per Mcf.


<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 2001.

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

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

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

Because  the  Partnership  does  not engage  in  drilling  activities,  the
development of proved undeveloped reserves 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 2001 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.

After  completion of the Partnership's first full fiscal year of operations
and each year thereafter, the Managing General Partner has offered and will
continue  to  offer  to  purchase each limited partner's  interest  in  the
Partnership,  at a price based on tangible assets of the Partnership,  plus
the  present  value  of  the future net revenues  of  proved  oil  and  gas
properties,  minus liabilities with a risk factor discount of  up  to  one-
third  which  may  be implemented at the sole discretion  of  the  Managing
General  Partner.   However, the Managing General Partner's  obligation  to
purchase  limited partner units is limited to an expenditure of  an  amount
not  in  excess  of  10%  of  the  total limited  partner  units  initially
subscribed for by limited partners.  In 2001, 2009.5 limited partner  units
were  tendered  to  and  purchased by the Managing General  Partner  at  an
average base price of $562.21 per unit. In 2000, 953 limited partner  units
were  tendered  to  and  purchased by the Managing General  Partner  at  an
average base price of $160.04 per unit.  In 1999, 117 limited partner units
were  tendered  to  and  purchased by the Managing General  Partner  at  an
average base price of $92.83 per unit.

Number of Limited Partner Interest Holders
As  of December 31, 2001 there were 669 holders of limited partner units in
the Partnership.

Distributions
Pursuant  to Article IV, Section 4.01 of the Partnership's Certificate  and
Agreement  of  Limited Partnership "Net Cash Flow" is  distributed  to  the
partners  on  a quarterly 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 at the sole  discretion  of  the
Managing General Partner."

<PAGE>

During  2001, distributions were made totaling $1,127,395, with  $1,014,895
distributed  to the limited partners and $112,500 to the general  partners.
For  the  year ended December 31, 2001, distributions of $50.74 per limited
partner   unit   were  made,  based  upon  20,000  limited  partner   units
outstanding.   During  2000,  quarterly distributions  were  made  totaling
$1,175,000,  with  $1,057,500  distributed  to  the  limited  partners  and
$117,500  to the general partners.  For the year ended December  31,  2000,
distributions  of  $52.88 per limited partner unit were  made,  based  upon
20,000 limited partner units outstanding.  Distributions for 2000 increased
significantly due to the record high oil and gas prices received during the
year.   During  1999,  distributions  were  made  totaling  $475,000,  with
$427,500  distributed to the limited partners and $47,500  to  the  general
partners.   For the year ended December 31, 1999, distributions  of  $21.38
per limited partner unit were made, based upon 20,000 limited partner units
outstanding.

Item 6.  Selected Financial Data

The  following  selected financial data for the years  ended  December  31,
2001,  2000,  1999,  1998 and 1997 should be read in conjunction  with  the
financial statements included in Item 8:

                                    Years ended December 31,
                  ------------------------------------------------------------
                       2001       2000       1999       1998         1997
                       ----       ----       ----       ----         ----
Revenues          $  964,152   1,435,664    830,452   367,745      964,866

Net income (loss)    571,669   1,215,573    523,863  (49,492)      526,063

Partners' share
 of net income (loss):

 General partners     57,167     121,557     52,386   (4,949)       52,607

 Limited partners    514,502   1,094,016    471,477  (44,543)      473,456

Limited partners'
 net income (loss)
                   per unit         25.73      54.70     23.57       (2.23)
23.67

Limited partners'
 cash distributions
                   per unit         50.74      52.88     21.38        19.91
41.81

Total assets      $1,688,419   2,242,902  2,202,052 2,152,173    2,641,528

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

General
The  Partnership was formed to acquire nonoperating 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  has  fluctuated  over  the past few  years  and  is  expected  to
fluctuate in later years based on these factors.

Based on current conditions, management anticipates performing no workovers
during  2002 to enhance production.  Additional workovers may be  performed
in  2003.   The partnership may have an increase in production volumes  for
the  year 2003, but thereafter, the partnership will most likely experience
the historical production decline of approximately 10% per year.

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.
<PAGE>
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.

Results of Operations

A.  General Comparison of the Years Ended December 31, 2001 and 2000

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 2001 and 2000:

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                2001      2000   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil         $      23.37     28.81   (19%)
Average price per mcf of gas            $       3.97      4.21    (6%)
Oil production in barrels                     29,000    33,200   (13%)
Gas production in mcf                        367,900   352,300      4%
Income from net profits interests       $    955,342 1,423,101   (33%)
Partnership distributions               $  1,127,395 1,175,000    (4%)
Limited partner distributions           $  1,014,985 1,057,500    (4%)
Per unit distribution to limited partners          $     50.74      52.88
(4%)
Number of limited partner units               20,000    20,000

Revenues

The  Partnership's income from net profits interests decreased to  $955,342
from   $1,423,101  for  the  years  ended  December  31,  2001  and   2000,
respectively,  a  decrease  of 33%.  The principal  factors  affecting  the
comparison of the years ended December 31, 2001 and 2000 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the year ended December 31, 2001 as compared  to  the
    year ended December 31, 2000 by 19%, or $5.44 per barrel, resulting  in
    a  decrease  of  approximately $157,800  in  income  from  net  profits
    interests.  Oil sales represented 32% of total oil and gas sales during
    the  year  ended December 31, 2001 as compared to 39% during  the  year
    ended December 31, 2000.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 6%, or $.24 per mcf, resulting in a
    decrease of approximately $88,300 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
    $246,100.  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 4,200 barrels or 13% during the
    year ended December 31, 2001 as compared to the year ended December 31,
    2000, resulting in a decrease of approximately $121,000 in income  from
    net profits interests.

    Gas production increased approximately 15,600 mcf or 4% during the same
    period,  resulting  in an increase of approximately $65,700  in  income
    from net profits interests.

    The  total net decrease in income from net profits interests due to the
    change in production is approximately $55,300.

3.  Lease  operating  costs  and  production  taxes  were  16%  higher,  or
    approximately $167,000 more during the year ended December 31, 2001  as
    compared  to the year ended December 31, 2000.  The increase  in  lease
    operating  expense is primarily due to pulling expense and  maintenance
    on two leases being performed in 2001.

Costs and Expenses

Total  costs and expenses increased to $392,483 from $220,091 for the years
ended  December 31, 2001 and 2000, respectively, an increase of  78%.   The
increase  is  primarily the result of higher depletion  expense,  partially
offset by a decrease in general and administrative costs.

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  decreased
   less  than  1% or approximately $600 during the year ended December  31,
   2001 as compared to the year ended December 31, 2000.

2. Depletion expense increased to $240,000 for the year ended December  31,
   2001  from  $67,000  for the same period in 2000.   This  represents  an
   increase  of 258%.  Depletion is calculated using the units  of  revenue
   method  of  amortization based on a percentage of current  period  gross
   revenues  to  total future gross oil and gas revenues, as  estimated  by
   the Partnership's independent petroleum consultants.

    The  major  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, 2002 as compared
    to  2001,  and  the decrease in oil and gas revenues  received  by  the
    Partnership  during  2001 as compared to 2000.  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  $80,000  as  of
    December 31, 2000.

<PAGE>

Results of Operations

B.  General Comparison of the Years Ended December 31, 2000 and 1999

The  following  table  provides certain information  regarding  performance
factors for the years ended December 31, 2000 and 1999:

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                2000      1999   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil         $      28.81     16.98     70%
Average price per mcf of gas            $       4.21      2.31     82%
Oil production in barrels                     33,200    43,840   (24%)
Gas production in mcf                        352,300   406,660   (13%)
Income from net profits interests       $  1,423,101   823,002     73%
Partnership distributions               $  1,175,000   475,000    147%
Limited partner distributions           $  1,057,500   427,500    147%
Per unit distribution to limited partners          $     52.88      21.38
147%
Number of limited partner units               20,000    20,000

Revenues

The Partnership's income from net profits interests increased to $1,423,101
from $823,002 for the years ended December 31, 2000 and 1999, respectively,
an  increase of 73%.  The principal factors affecting the comparison of the
years ended December 31, 2000 and 1999 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the year ended December 31, 2000 as compared  to  the
    year ended December 31, 1999 by 70%, or $11.83 per barrel, resulting in
    an  increase  of  approximately $392,800 in  income  from  net  profits
    interests.  Oil sales represented 39% of total oil and gas sales during
    the  year  ended December 31, 2000 as compared to 44% during  the  year
    ended December 31, 1999.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 82%, or $1.90 per mcf, resulting in
    an  increase  of  approximately $669,400 in  income  from  net  profits
    interests.

    The  total  increase in income from net profits interests  due  to  the
    change  in prices received from oil and gas production is approximately
    $1,062,200.   The  market  price for oil and  gas  has  been  extremely
    volatile  over the past decade and management expects a certain  amount
    of volatility to continue in the foreseeable future.

<PAGE>

2.  Oil production decreased approximately 10,640 barrels or 24% during the
    year ended December 31, 2000 as compared to the year ended December 31,
    1999, resulting in a decrease of approximately $180,700 in income  from
    net profits interests.

    Gas  production  decreased approximately 54,360 mcf or 13%  during  the
    same  period,  resulting  in  a decrease of approximately  $125,600  in
    income from net profits interests.

    The  total  decrease in income from net profits interests  due  to  the
    change  in  production  is  approximately $306,300.   The  decrease  in
    production is due primarily to one well, which a workover was preformed
    on during the first quarter of 1999, dramatically increasing production
    during the second quarter of 1999.  This same well by year end 1999 had
    shut down and was no longer a producing well, thus the decrease for the
    twelve months ended December 31, 2000.

3.  Lease  operating  costs  and  production  taxes  were  18%  higher,  or
    approximately $153,500 more during the year ended December 31, 2000  as
    compared  to the year ended December 31, 1999.  The increase  in  lease
    operating  costs and production taxes is due in part to an increase  in
    major  repairs  and maintenance and in part to the rise  in  production
    taxes  directly associated with the rise in oil and gas prices received
    during  the  past year.  The rise in oil and gas prices  for  2000  has
    allowed the Partnership to perform these repairs and maintenance in the
    hopes of increasing production, thereby increasing revenues.

Costs and Expenses

Total  costs and expenses decreased to $220,091 from $306,589 for the years
ended  December 31, 2000 and 1999, respectively, a decrease  of  28%.   The
decrease  is  primarily  the result of lower depletion  expense,  partially
offset by an increase in general and administrative costs.

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  2%
   or  approximately  $2,500 during the year ended  December  31,  2000  as
   compared to the year ended December 31, 1999.

2. Depletion  expense decreased to $67,000 for the year ended December  31,
   2000  from  $156,000  for the same period in 1999.   This  represents  a
   decrease  of  57%.  Depletion is calculated using the units  of  revenue
   method  of  amortization based on a percentage of current  period  gross
   revenues  to  total future gross oil and gas revenues, as  estimated  by
   the Partnership's independent petroleum consultants.

    The  major  factor  to  the decrease in depletion expense  between  the
    comparative periods was the increase in the price of oil and  gas  used
    to determine the Partnership's reserves for January 1, 2001 as compared
    to  2000.   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 $14,000 as of December 31, 1999.

<PAGE>

C.  Revenue and Distribution Comparison

Partnership net income for the years ended December 31, 2001, 2000 and 1999
was $571,669, $1,215,573 and $523,863, respectively.  Excluding the effects
of depreciation, depletion and amortization, net income for the years ended
December  31, 2001, 2000 and 1999 would have been $811,669, $1,282,573  and
$679,863, respectively.  Correspondingly, Partnership distributions for the
years  ended  December 31, 2001, 2000 and 1999 were $1,127,395,  $1,175,000
and  $475,000,  respectively.   These differences  are  indicative  of  the
changes in oil and gas prices, production and properties during 2001,  2000
and 1999.

The  sources  for  the 2001 distributions of $1,127,395 were  oil  and  gas
operations  of  approximately $1,095,000, with the balance  from  available
cash  on  hand  at the beginning of the period.  The sources for  the  2000
distributions  of  $1,175,000 were oil and gas operations of  approximately
$1,154,900  and  the  change  in oil and gas  properties  of  approximately
$2,500,  with  the balance from available cash on hand at the beginning  of
the  period.  The sources for the 1999 distributions of $475,000  were  oil
and  gas operations of approximately $616,600, resulting in excess cash for
contingencies or subsequent distributions.

Total distributions during the year ended December 31, 2001 were $1,127,395
of which $1,014,895 was distributed to the limited partners and $112,500 to
the general partners.  The per unit distribution to limited partners during
the  same  period was $50.74.  Total distributions during  the  year  ended
December  31,  2000 were $1,175,000 of which $1,057,500 was distributed  to
the  limited partners and $117,500 to the general partners.  The  per  unit
distribution to limited partners during the same period was $52.88.   Total
distributions  during  the year ended December 31, 1999  were  $475,000  of
which  $427,500 was distributed to the limited partners and $47,500 to  the
general partners.  The per unit distribution to limited partners during the
same period was $21.38.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $17,453,854 have been made to the partners.  As of December  31,  2001,
$15,724,177  or  $786.21 per limited partner unit, has been distributed  to
the   limited   partners,  representing  a  157%  return  of  the   capital
contributed.

<PAGE>

Liquidity and Capital Resources
The  primary source of cash is from operations, the receipt of income  from
net profits 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 $1,095,000
in  2001 compared to $1,154,900 in 2000 and approximately $616,600 in 1999.
The  primary  source  of the 2001 cash flow from operating  activities  was
profitable operations.

There was no cash flows provided by investing activities during 2001.  Cash
flows  provided by investing activities were approximately $2,500 in  2000.
The Partnership had no cash flows from investing activities in 1999.

Cash  flows  used in financing activities were approximately $1,126,000  in
2001  compared  to $1,175,000 in 2000 and approximately $474,000  in  1999.
The only use in financing activities was the distributions to partners.

As  of  December  31, 2001, the Partnership had approximately  $147,400  in
working  capital.   The  Managing  General  Partner  knows  of  no  unusual
contractual commitments and believes the revenue 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 $113,744 at December  31,
2001, and recognized a net loss in the fourth quarter of 2001 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.

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.
<PAGE>
Recent Accounting Pronouncements

In  June  1998,  the Financial Accounting Standards Board  ("FASB")  issued
Statement  of  Financial Accounting Standards ("SFAS") No.133,  "Accounting
for  Derivative  Instruments and Hedging Activities."   SFAS  No.  133,  as
amended by SFAS No. 138, establishes accounting and reporting standards for
derivative  instruments, including certain derivative instruments  embedded
in  other contracts and for hedging activities.  Assessment by the Managing
General  Partner  revealed this pronouncement to  have  no  impact  on  the
partnerships.

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

Item 7A.  Quantitative and Qualitative Disclosures About Market Risk

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


<PAGE>

Item 8.   Financial Statements and Supplementary Data

                      Index to Financial Statements

                                                                       Page

Independent Auditors Report                                             21

Balance Sheets                                                          22

Statements of Operations                                                23

Statement of Changes in Partners' Equity                                24

Statements of Cash Flows                                                25

Notes to Financial Statements                                           27

<PAGE>










                        INDEPENDENT AUDITORS REPORT

The Partners
Southwest Royalties, Inc. Income Fund VI
(A Tennessee Limited Partnership):


We  have  audited  the accompanying balance sheets of Southwest  Royalties,
Inc.  Income Fund VI (the "Partnership") as of December 31, 2001 and  2000,
and  the related statements of operations, changes in partners' equity  and
cash  flows  for each of the years in the three year period ended  December
31,  2001.   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 auditing standards  generally
accepted in the United States of America.  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  Royalties,
Inc. Income Fund VI as of December 31, 2001 and 2000 and the results of its
operations  and  its cash flows for each of the years  in  the  three  year
period  ended  December  31, 2001 in conformity with  generally  accounting
principles generally accepted in the United States of America.








                                                  KPMG LLP



Midland, Texas
March 10, 2002

<PAGE>


                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                              Balance Sheets
                        December 31, 2001 and 2000


                                                      2001          2000
                                                      ----          ----
  Assets
  ------

Current assets:
 Cash and cash equivalents                   $       132,282      163,762
 Receivable from Managing General Partner             18,003      301,006

---------                                    ---------
                                                 Total    current    assets
150,285                                      464,768

---------                                    ---------
Oil and gas properties - using the full-
 cost method of accounting                         8,424,134    8,424,134
  Less accumulated depreciation,
                                               depletion  and  amortization
6,886,000                                    6,646,000

---------                                    ---------
                                              Net  oil  and gas  properties
1,538,134                                    1,778,134

---------                                    ---------
                                                                          $
1,688,419                                    2,242,902

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

Current liability - distribution payable     $         2,837        1,594

---------                                    ---------
Partners' equity:
 General partners                                  (685,772)    (630,439)
 Limited partners                                  2,371,354    2,871,747

---------                                    ---------
                                                Total    partners'   equity
1,685,582                                    2,241,308

---------                                    ---------
                                                                          $
1,688,419                                    2,242,902

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





















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

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                         Statements of Operations
               Years ended December 31, 2001, 2000 and 1999


                                                             2001      2000
1999
                                                             ----      ----
----
  Revenues
  --------

Income from net profits interests         $    955,342 1,423,101  823,002
Interest                                         8,810    12,563    7,450
                                                                  ---------
---------                                 ---------
                                                                    964,152
1,435,664                                 830,452
                                                                  ---------
---------                                 ---------
  Expenses
  --------

General and administrative                     152,483   153,091  150,589
Depreciation, depletion and amortization       240,000    67,000  156,000
                                                                  ---------
---------                                 ---------
                                                                    392,483
220,091                                   306,589
                                                                  ---------
---------                                 ---------
Net income                                $    571,669 1,215,573  523,863
                                                                  =========
=========                                 =========
Net income allocated to:

 Managing General Partner                 $     51,450   109,401   47,147
                                                                  =========
=========                                 =========
 General partner                          $      5,717    12,156    5,239
                                                                  =========
=========                                 =========
 Limited partners                         $    514,502 1,094,016  471,477
                                                                  =========
=========                                 =========
  Per limited partner unit                $      25.73     54.70    23.57
                                                                  =========
=========                                 =========
























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

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                 Statement of Changes in Partners' Equity
               Years ended December 31, 2001, 2000 and 1999


                                            General    Limited
                                            Partners   Partners    Total
                                            --------   --------    -----
Balance at December 31, 1998            $ (639,382)   2,791,254 2,151,872

 Net income                                  52,386     471,477   523,863

 Distributions                             (47,500)   (427,500) (475,000)
                                                                   --------
----------                              ----------
Balance at December 31, 1999              (634,496)   2,835,231 2,200,735

 Net income                                 121,557   1,094,016 1,215,573

 Distributions                            (117,500) (1,057,500)(1,175,000)
                                                                   --------
----------                              ----------
Balance at December 31, 2000              (630,439)   2,871,747 2,241,308

 Net income                                  57,167     514,502   571,669

 Distributions                            (112,500) (1,014,895)(1,127,395)
                                                                   --------
----------                              ----------
Balance at December 31, 2001            $ (685,772)   2,371,354 1,685,582
                                                                   ========
==========                              ==========






























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

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                         Statements of Cash Flows
               Years ended December 31, 2001, 2000 and 1999


                                                             2001      2000
1999
                                                             ----      ----
----
Cash flows from operating activities:

 Cash received from net profits interests $  1,237,440 1,298,078  766,709
 Cash paid to Managing General Partner
  for administrative fees and general
                                            and   administrative   overhead
(151,578)                                 (155,768)(157,603)
 Interest received                               8,810    12,563    7,450
                                                                  ---------
---------                                 ---------
   Net  cash provided by operating activities            1,094,6721,154,873
616,556
                                                                  ---------
---------                                 ---------
Cash provided by investing activities:

 Sale of oil and gas properties                      -     2,500        -
                                                                  ---------
---------                                 ---------
Cash used in financing activities:

 Distributions to partners                 (1,126,152)(1,174,723)(473,983)
                                                                  ---------
---------                                 ---------
Net (decrease) increase in cash and cash
 equivalents                                  (31,480)  (17,350)  142,573

 Beginning of year                             163,762   181,112   38,539
                                                                  ---------
---------                                 ---------
 End of year                              $    132,282   163,762  181,112
                                                                  =========
=========                                 =========


(continued)
























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

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                   Statements of Cash Flows, continued
               Years ended December 31, 2001, 2000 and 1999


                                                             2001      2000
1999
                                                             ----      ----
----
Reconciliation of net income to net
 cash provided by operating activities:

Net income                                $    571,669 1,215,573  523,863

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

   Depreciation, depletion and amortization               240,000    67,000
156,000
  Decrease (increase) in receivables           282,098 (125,023) (56,294)
  Increase (decrease) in payables                  905   (2,677)  (7,013)
                                                                  ---------
--------                                  -------
Net cash provided by operating activities $  1,094,672 1,154,873  616,556
                                                                  =========
========                                  =======






































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

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

1.  Organization
          Southwest Royalties, Inc. Income Fund VI was organized under  the
    laws of the state of Tennessee on December 4, 1986, for the purpose  of
    acquiring  producing oil and gas properties and to produce  and  market
    crude  oil and natural gas produced from such properties for a term  of
    50  years, unless terminated at an earlier date as provided for in  the
    Partnership  Agreement.   The  Partnership  sells  its  oil   and   gas
    production to a variety of purchasers with the prices it receives being
    dependent  upon  the  oil and gas economy.  Southwest  Royalties,  Inc.
    serves  as the Managing General Partner and H. H. Wommack, III, as  the
    individual  general partner.  Effective December 31, 2001, Mr.  Wommack
    sold  his  general  partner interest to the Managing  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%           -
    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                        90%          10%
    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 Royalties, Inc. Income Fund VI
                    (a Tennessee 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, 2001, 2000  and  1999,
    the net capitalized costs did not exceed the estimated present value of
    oil and gas reserves.

    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.

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

2.  Summary of Significant Accounting Policies - continued

    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.  The Partnerships  depletion
    calculation and full cost ceiling test for oil and gas properties  uses
    oil  and gas reserve estimates, which are inherently imprecise.  Actual
    results could differ from those estimates.

         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, 2001, 2000 and 1999,
    the Partnership was over produced by 1,014, 6,004 and 1,429 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,  2001 and 2000 is $959,132 and $1,076,779, respectively, less  than
    that  shown  on  the  accompanying Balance Sheets  in  accordance  with
    generally accepted accounting principles.

    Cash and Cash Equivalents
    For purposes of the statements 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,  2001, 2000 and 1999, there were  20,000  limited
    partner units outstanding held by 669, 767 and 826 partners.
<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee 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.

   Recent Accounting Pronouncements
   In  June 1998, the Financial Accounting Standards Board ("FASB")  issued
   Statement   of   Financial   Accounting   Standards   ("SFAS")   No.133,
   "Accounting  for  Derivative Instruments and Hedging Activities."   SFAS
   No.  133,  as  amended  by  SFAS  No. 138,  establishes  accounting  and
   reporting  standards  for  derivative  instruments,  including   certain
   derivative  instruments  embedded in other  contracts  and  for  hedging
   activities.   Assessment by the Managing General Partner  revealed  this
   pronouncement to have no impact on the partnerships.

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

3.  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.

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

3.  Liquidity - Managing General Partner - continued
    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.

4.  Commitments and Contingent Liabilities
    After  completion  of  the  Partnership's first  full  fiscal  year  of
    operations  and each year thereafter, the Managing General Partner  has
    offered  and will continue to offer to purchase each limited  partner's
    interest in the Partnership, at a price based on tangible assets of the
    Partnership,  plus  the  present value of the future  net  revenues  of
    proved  oil  and gas properties, minus liabilities with a  risk  factor
    discount  of  up  to  one-third which may be implemented  at  the  sole
    discretion  of  the  Managing General Partner.  However,  the  Managing
    General  Partner's  obligation to purchase  limited  partner  units  is
    limited  to  an expenditure of an amount not in excess of  10%  of  the
    total  limited  partner  units  initially  subscribed  for  by  limited
    partners.

    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, 2001, 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 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 the Partnership's properties.

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee 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 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 $105,000,  $103,300
    and  $105,400,  for the years ended December 31, 2001, 2000  and  1999,
    respectively.   In addition, the Managing General Partner  and  certain
    officers  and employees may have an interest in some of the  properties
    in which 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
    $10,000,  $54,800 and $75,500, for the years ended December  31,  2001,
    2000 and 1999, respectively.

    Southwest  Royalties,  Inc., the Managing  General  Partner,  was  paid
    $144,000  during  2001,  2000 and 1999, as an  administrative  fee  for
    indirect general and administrative overhead expenses.

    Receivables  from  Southwest  Royalties,  Inc.,  the  Managing  General
    Partner,  of  approximately $18,000 and $301,000 are from oil  and  gas
    production,  net of lease operating costs and production taxes,  as  of
    December 31, 2001 and 2000, 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  approximating $1,000, $1,300 and $900 for the years  ended
    December 31, 2001, 2000 and 1999, respectively.

6.  Major Customers
    No  material  portion of the Partnership's business is dependent  on  a
    single purchaser, or a very few purchasers, where the loss of one would
    have  a  material  adverse impact on the Partnership.   Two  purchasers
    accounted  for  68% of the Partnership's total oil and  gas  production
    during  2001:  Duke Energy Field Services for 55% and Plains  Marketing
    LP  for  13%.   Two  purchasers accounted for 59% of the  Partnership's
    total oil and gas production during 2000:  Phillips 66 Natural Gas  Co.
    for  48%  and Plain Marketing, LP for 11%.  Three purchasers  accounted
    for  64% of the Partnership's total oil and gas production during 1999:
    Phillips 66 Natural Gas Co. for 42%, Scurlock Permian LLC for  11%  and
    Genesis Crude Oil 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.

<PAGE>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee 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, 1999                                256,000      5,083,000

      Revisions of previous estimates              215,000      1,078,000
      Production                                  (44,000)      (407,000)
                                                   -------      ---------
    December 31, 1999                              427,000      5,754,000

      Revisions of previous estimates              (6,000)        220,000
      Production                                  (33,000)      (352,000)
                                                   -------      ---------
    December 31, 2000                              388,000      5,622,000

      Revisions of previous estimates            (221,000)        114,000
      Production                                  (29,000)      (368,000)
                                                   -------      ---------
    December 31, 2001                              138,000      5,368,000
                                                   =======      =========
    Proved developed reserves -

    December 31, 1999                              385,000      5,398,000
                                                   =======      =========
    December 31, 2000                              308,000      5,196,000
                                                   =======      =========
    December 31, 2001                               98,000      5,017,000
                                                   =======      =========

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

    *Ryder Scott Petroleum Engineers prepared the reserve and present value
    data  for the Partnership's existing properties as of January 1,  2002.
    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.

   Oil  price  adjustments  were  made in  the  individual  evaluations  to
   reflect  oil  quality, gathering and transportation costs.  The  results
   of  the  reserve  report as of January 1, 2002 are an average  price  of
   $18.50 per barrel.

    Gas  price  adjustments  were  made in the  individual  evaluations  to
    reflect  BTU  content,  gathering  and  transportation  costs  and  gas
    processing  and  shrinkage.  The results of the reserve  report  as  of
    January 1, 2002 are an average price of $2.14 per Mcf.

<PAGE>
                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

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

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

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

    Because  the  Partnership does not engage in drilling  activities,  the
    development  of  proved undeveloped reserves 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 Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

7.  Estimated Oil & Gas Reserves (unaudited) - continued
    The  standardized measure of discounted future net cash flows  relating
    to  proved oil and gas reserves at December 31, 2001, 2000 and 1999  is
    presented below:

                                             2001       2000         1999
                                             ----       ----         ----

     Future cash inflows, net of
                                        production and development
      costs                             $  9,769,000 49,205,000 14,581,000
     10% annual discount for
                                        estimated timing of cash
      flows                                5,238,000 26,968,000  6,733,000
                                          ---------- ---------- ----------
     Standardized measure of
                                        discounted future net cash
      flows                             $  4,531,000 22,237,000  7,848,000
                                          ========== ========== ==========

     The  principal  sources  of  change in  the  standardized  measure  of
     discounted  future  net cash flows for the years  ended  December  31,
     2001, 2000 and 1999 are as follows:

                                             2001        2000        1999
                                             ----        ----        ----

     Sales of oil and gas produced,
                                         net of production costs          $
(955,000)                               (1,423,000)   (823,000)
     Changes in prices and production
       costs                           (16,948,000)  15,689,000  2,271,000
     Changes in estimated future development
                                       cost                    -    105,000
(122,000)
     Changes of production rates
       (timing) and others              (1,136,000) (1,282,000)   (25,000)
     Sales of minerals in place                   -     (2,000)          -
     Revisions of previous
                                       quantities estimates       (891,000)
517,000                               2,278,000
     Accretion of discount                2,224,000     785,000    388,000
     Discounted future net
                                      cash flows -
      Beginning of year                  22,237,000   7,848,000  3,881,000
                                         ----------  ---------- ----------
      End of year                       $ 4,531,000  22,237,000  7,848,000
                                         ==========  ========== ==========

     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>

                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)

                      Notes to Financial Statements

8.  Selected Quarterly Financial Results - (unaudited)

                                                 Quarter
                              ----------------------------------------------
                                 First       Second    Third       Fourth
                                 ------     -------    ------      ------
  2001:
     Total revenues           $  541,689    331,459   118,364    (27,360)
     Total expenses               77,358     98,963   142,226      73,936
     Net income (loss)           464,331    232,496  (23,862)   (101,296)
     Net income (loss) per limited
      partners unit                20.89      10.46     (1.07)     (4.55)

  2000:
     Total revenues           $  352,100    371,794   390,211     321,559
     Total expenses               78,492     49,386    60,911      31,302
     Net income                  273,608    322,408   329,300     290,257
     Net income per limited
      partners unit                12.31      14.51     14.82       13.06


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

          None

<PAGE>

                                 Part III


Item 10.  Directors and Executive Officers of the Registrant

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

     Name                   Age                       Position
--------------------        ---         -----------------------------------
-------
H. H. Wommack, III                      46     Chairman   of   the   Board,
                                        President,
                                        Chief Executive Officer, Treasurer
                                        and Director

H. Allen Corey              45          Secretary and Director

Bill E. Coggin                          47     Vice  President  and   Chief
                                        Financial Officer

J. Steven Person            43          Vice President, Marketing

Paul L. Morris              60          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.

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.B.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 the Columbia Gas  System,
Inc.

Key Employees

Jon  P. Tate, Vice President, Land and Assistant Secretary, age 44, 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 American Association of Petroleum Landmen.   Mr.
Tate received his B.B.S. degree from Hardin-Simmons University.

R.  Douglas  Keathley,  Vice President, Operations,  age  46,  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.


<PAGE>

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  $144,000  during 2001, 2000 and 1999 as an annual  administrative
fee.

Item 12.  Security Ownership of Certain Beneficial Owners and Management

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

The  Managing  General Partner owns a nine percent interest  as  a  general
partner.   Through repurchase offers to the limited partners, the  Managing
General  Partner also owns 7,073.5 limited partner units, a  35.4%  limited
partner  interest.  The Managing General Partners total percentage interest
ownership in the Partnership is 40.8%.

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 Managing General Partner as of December 31, 2001, repurchased
the  one  percent interest owned by Mr. Wommack for approximately $123,513.
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     35.4%
                      Interest                     Managing General Partner
7,073.5 Units
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  H. H. Wommack, III           Indirectly Owns   35.4%
                      Interest                      Chairman of the  Board,
7,073.5 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   35.4%
                     Interest                     Secretary and Director of
7,073.5 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     633 Chestnut Street
                     Chattanooga, TN  37450-1800

Limited Partnership  Bill E. Coggin               Indirectly Owns   35.4%
                     Interest                     Vice President and CFO of
7,073.5 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  J. Steven Person             Indirectly Owns   35.4%
                     Interest                     Vice President, Marketing
7,073.5 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  Paul L. Morris               Indirectly Owns   35.4%
                      Interest                      Director  of  Southwest
7,073.5 Units
                     Royalties, Inc., the
                     Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

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

<PAGE>
Item 13.  Certain Relationships and Related Transactions

In   2001,   the   Managing  General  Partner  received  $144,000   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 net profits interest.  Certain properties
in  which  the  Partnership has an interest are operated  by  the  Managing
General  Partner,  who was paid approximately $105,000  for  administrative
overhead attributable to operating such properties during 2001.

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 $10,000  for  the  year
ended December 31, 2001

The  law  firm  of Baker, Donelson, Bearman & Caldwell of  which  H.  Allen
Corey,  an  officer  and  director of the Managing General  Partner,  is  a
partner, is counsel to the Partnership.  Legal services rendered by  Baker,
Donelson,   Bearman  &  Caldwell  to  the  Partnership  during  2001   were
approximately  $1,000,  which constitutes an  immaterial  portion  of  that
firm's business.

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

<PAGE>

                                 Part IV


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

          (a)(1)  Financial Statements:

                  Included in Part II of this report --

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

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

                    (3)  Exhibits:

                                     4    (a)  Certificate and Agreement of
                          Limited Partnership of Southwest Royalties,  Inc.
                          Income   Fund   VI,  dated  December   4,   1986.
                          (Incorporated  by  reference  from  Partnership's
                          Form 10-K for the fiscal year ended December  31,
                          1986.)

                                            (b)     First   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated   January   16,1987.    (Incorporated    by
                          reference  from Partnership's Form 10-K  for  the
                          fiscal year ended December 31, 1987.)

                                         (c)  Corrected Second Amendment to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  May  6, 1987.  (Incorporated by  reference
                          from  Partnership's Form 10-K for the fiscal year
                          ended December 31, 1987.)

                                            (d)     Third   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated February 3, 1988 (Incorporated by reference
                          from  Partnership's Form 10-K for the fiscal year
                          ended December 31, 1988.)

                                            (e)    Fourth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  June  30, 1988 (Incorporated by  reference
                          from  Partnership's Form 10-K for the fiscal year
                          ended December 31, 1988.)

<PAGE>

                                            (f)     Fifth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated   December   30,  1988   (Incorporated   by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1988.)

                                            (g)     Sixth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  March 19, 1990.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1990.)

                                            (h)    Seventh   Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1990.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1990.)

                                            (i)    Eighth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of September 30, 1991.  (Incorporated by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1991.)

                                            (j)     Ninth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1991.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                            (k)     Tenth   Amendment    to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  March 31, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                           (l)    Eleventh   Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  June  30, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

                                            (m)    Twelfth   Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of November 23, 1992.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1992.)

<PAGE>

                                           (n)   Thirteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  April 22, 1993.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                           (o)   Fourteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of September 30, 1993.  (Incorporated by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                           (p)    Fifteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 31, 1993.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1993.)

                                           (q)    Sixteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as  of  July  26, 1994.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1994.)

                                           (r)   Seventeenth  Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated  as of January 18, 1995.  (Incorporated  by
                          reference  from the Partnership's Form  10-K  for
                          the fiscal year ended December 31, 1994.)

                                           (s)   Eighteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 26, 1995.

                                           (t)   Nineteenth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of January 29, 1996.

<PAGE>

                                           (u)    Twentieth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of April 30, 1996.

                     (v)  Twenty First Amendment to Certificate and Agreement
of Limited
                          Partnership of Southwest Royalties, Inc.
Income Fund VI,
dated as of
                          September 30, 1996.

                     (w)  Twenty Second Amendment to Certificate and
Agreement of Limited
                          Partnership of Southwest Royalties, Inc.
Income Fund VI,
dated as of
                          January 15, 1997.

                                          (x)   Twenty  Third Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of May 10, 1997.

                          (y)   Twenty Fourth Amendment to Certificate  and
                          Agreement  of  Limited Partnership  of  Southwest
                          Royalties,  Inc.  Income Fund  VI,  dated  as  of
                          January 30, 1998.

                          (z)   Twenty  Fifth Amendment to Certificate  and
                          Agreement of
                          Limited Partnership of Southwest Royalties,  Inc.
                          Income Fund VI, dated as of July 27, 1998.

                                          (aa)  Twenty  Sixth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of December 22, 1998.

                                          (bb) Twenty Seventh Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 25, 1999.

                                          (cc)  Twenty Eighth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 27, 1999.

                                          (dd)  Twenty  Ninth Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 10, 2000.

                                           (ee)   Thirtieth  Amendment   to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of April 26, 2000.

                                          (ff)  Thirty  First Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of September 13, 2000.

                                          (gg)  Thirty Second Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of February 20, 2001.

                                          (hh)  Thirty  Third Amendment  to
                          Certificate  and Agreement of Limited Partnership
                          of  Southwest  Royalties, Inc.  Income  Fund  VI,
                          dated as of July 16, 2001.

                  99 Limited Partners as of February 20, 2001
                     Limited Partners as of July 16, 2001

               (b)    Reports on Form 8-K

                      There  were no reports filed on Form 8-K  during  the
               quarter ended December 31, 2001.

<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 Royalties, Inc. Income Fund VI, a
                          Tennessee limited partnership


                          By:    Southwest Royalties, Inc., Managing
                                 General Partner


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


                          Date:  April 11, 2002


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:  April 11, 2002


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


Date:  April 11, 2002

<PAGE>

                              Exhibit Index


Item No.     Description                                           Page No.

14(a)(3)       Exhibit  4(gg):  Thirty  Second  Amendment  to   Certificate
47
             and Agreement of Limited Partnership of Southwest
             Royalties, Inc. Income Fund VI, dated as of
             February 20, 2001.

             Exhibit 4 (hh): Thirty Third Amendment to Certificate  49
             and Agreement of Limited Partnership of Southwest
             Royalties, Inc. Income Fund VI, dated as of
             July 16, 2001.


<PAGE>

This Instrument Prepared By:
J. Porter Durham, Jr.
Baker, Donelson, Bearman & Caldwell
1800 Republic Centre
633 Chestnut Street
Chattanooga, Tennessee 37450-1800

         THIRTY-SECOND AMENDMENT TO CERTIFICATE AND AGREEMENT OF
             LIMITED PARTNERSHIP OF SOUTHWEST ROYALTIES, INC.
             INCOME FUND VI, A TENNESSEE LIMITED PARTNERSHIP

Pursuant  to the Tennessee Revised Uniform Limited Partnership  Act,  62-2-
1204  of  the Tennessee Code Annotated, and the provisions of the Tennessee
Uniform  Limited Partnership Act, being formerly 61-2-101, et seq.  of  the
Tennessee Code Annotated, this Thirty-second Amendment (the "Amendment") to
the   Certificate  and  Agreement  of  Limited  Partnership  of   Southwest
Royalties, Inc.  Income Fund VI is executed to be effective as of the  31st
day  of  December, 2000, by and between H. H. WOMMACK, III,  an  individual
("General Partner"), SOUTHWEST ROYALTIES, INC. ("Managing General Partner")
(the  Managing  General  Partner and the General Partner,  are  hereinafter
collectively  referred to as "General Partners"), and the General  Partners
as  attorney-in-fact for those persons and entities listed  on  Schedule  1
attached to this Amendment, whether existing or additional limited partners
(collectively  the  "Limited  Partners") and as  attorney-in-fact  for  the
Withdrawing Limited Partners, as defined hereinafter.

WHEREAS,  Southwest  Royalties, Inc.  Income Fund VI  was  organized  as  a
Tennessee   limited  partnership  pursuant  to  an  Agreement  of   Limited
Partnership,  as  amended from time to time, dated  December  4,  1986  and
recorded  in  Book  3280,  Page 726 in the Register's  Office  of  Hamilton
County, Tennessee (the "Agreement"); and

WHEREAS,  the  General Partners, Limited Partners and  Withdrawing  Limited
Partners desire to amend the Agreement in the manner set forth herein;

NOW,  THEREFORE,  for  and  in  consideration  of  the  mutual  rights  and
obligations  herein and other good and valuable consideration  the  receipt
and  legal sufficiency of which are acknowledged, the parties hereto  agree
as follows:

1.   Schedule  1  to  the Agreement is hereby deleted in its  entirety  and
     replaced  by  the  Schedule  1 attached  hereto.   Those  persons  and
     entities which were formerly listed on Schedule 1 to the Agreement but
     which  are not listed on the revised Schedule 1 attached hereto  shall
     be defined collectively as the "Withdrawing Limited Partners."

2.   Except  as  provided herein, the Agreement is hereby  constituted  and
     acknowledged as the controlling Agreement of Southwest Royalties, Inc.
     Income Fund VI.
<PAGE>
IN  WITNESS WHEREOF, the parties hereto acknowledge that they have executed
this  Amendment to the Agreement to be effective as of the date first above
written.

               GENERAL PARTNERS:

               By:  /s/ H. H. Wommack, III
                    -----------------------------------
                    H. H. Wommack, III, General Partner

               By:   SOUTHWEST ROYALTIES, INC.
                    Managing General Partner

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


               LIMITED PARTNERS:


                               By:   General Partners, as attorneys-in-fact
                    for  the Limited Partners listed on Schedule 1 attached
                    hereto  and those Withdrawing Limited Partners  removed
                    from  Schedule  1  under Powers of Attorney  previously
                    granted

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

               By:  SOUTHWEST ROYALTIES, INC.
                    Managing General Partner

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

STATE OF TEXAS      )
COUNTY OF MIDLAND      )

Before  me,  /s/ B. Ross, a Notary Public in and for the State  and  County
aforesaid, personally appeared H.H. Wommack, III, with whom I am personally
acquainted  (or  proved to me on the basis of satisfactory  evidence),  and
who,  upon  oath, acknowledged himself to be the attorney-in-fact  for  the
admitted  and  withdrawing Limited Partners and as president  of  Southwest
Royalties,  Inc.  for itself and as attorney-in-fact for the  admitted  and
withdrawing  Limited  Partners, and who further  acknowledged  that  he  is
authorized  by  Southwest  Royalties, Inc., the Limited  Partners  and  the
Withdrawing  Limited Partners to execute this document  on  its  and  their
behalf.

Witness my hand and seal at office, on this the 20 day of February, 2001.

                    /s/ B.Ross
                    -----------------------------------
                    Notary Public

My commission expires:
08/30/03

<PAGE>

This Instrument Prepared By:
J. Porter Durham, Jr.
Baker, Donelson, Bearman & Caldwell
1800 Republic Centre
633 Chestnut Street
Chattanooga, Tennessee 37450-1800

          THIRTY-THIRD AMENDMENT TO CERTIFICATE AND AGREEMENT OF
             LIMITED PARTNERSHIP OF SOUTHWEST ROYALTIES, INC.
             INCOME FUND VI, A TENNESSEE LIMITED PARTNERSHIP

Pursuant  to the Tennessee Revised Uniform Limited Partnership  Act,  62-2-
1204  of  the Tennessee Code Annotated, and the provisions of the Tennessee
Uniform  Limited Partnership Act, being formerly 61-2-101, et seq.  of  the
Tennessee Code Annotated, this Thirty-Third Amendment (the "Amendment")  to
the   Certificate  and  Agreement  of  Limited  Partnership  of   Southwest
Royalties, Inc.  Income Fund VI is executed to be effective as of the  30th
day  of  June,  2001,  by  and between H. H. WOMMACK,  III,  an  individual
("General Partner"), SOUTHWEST ROYALTIES, INC. ("Managing General Partner")
(the  Managing  General  Partner and the General Partner,  are  hereinafter
collectively  referred to as "General Partners"), and the General  Partners
as  attorney-in-fact for those persons and entities listed  on  Schedule  1
attached to this Amendment, whether existing or additional limited partners
(collectively  the  "Limited  Partners") and as  attorney-in-fact  for  the
Withdrawing Limited Partners, as defined hereinafter.

WHEREAS,  Southwest  Royalties, Inc.  Income Fund VI  was  organized  as  a
Tennessee   limited  partnership  pursuant  to  an  Agreement  of   Limited
Partnership,  as  amended from time to time, dated  December  4,  1986  and
recorded  in  Book  3280,  Page 726 in the Register's  Office  of  Hamilton
County, Tennessee (the "Agreement"); and

WHEREAS,  the  General Partners, Limited Partners and  Withdrawing  Limited
Partners desire to amend the Agreement in the manner set forth herein;

NOW,  THEREFORE,  for  and  in  consideration  of  the  mutual  rights  and
obligations  herein and other good and valuable consideration  the  receipt
and  legal sufficiency of which are acknowledged, the parties hereto  agree
as follows:

1.   Schedule  1  to  the Agreement is hereby deleted in its  entirety  and
     replaced  by  the  Schedule  1 attached  hereto.   Those  persons  and
     entities which were formerly listed on Schedule 1 to the Agreement but
     which  are not listed on the revised Schedule 1 attached hereto  shall
     be defined collectively as the "Withdrawing Limited Partners."

2.   Except  as  provided herein, the Agreement is hereby  constituted  and
     acknowledged as the controlling Agreement of Southwest Royalties, Inc.
     Income Fund VI.

<PAGE>
IN  WITNESS WHEREOF, the parties hereto acknowledge that they have executed
this  Amendment to the Agreement to be effective as of the date first above
written.

               GENERAL PARTNERS:

               By:  /s/ H. H. Wommack, III
                    -----------------------------------
                    H. H. Wommack, III, General Partner

               By:   SOUTHWEST ROYALTIES, INC.
                    Managing General Partner

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


               LIMITED PARTNERS:


                               By:   General Partners, as attorneys-in-fact
                    for  the Limited Partners listed on Schedule 1 attached
                    hereto  and those Withdrawing Limited Partners  removed
                    from  Schedule  1  under Powers of Attorney  previously
                    granted

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

               By:  SOUTHWEST ROYALTIES, INC.
                    Managing General Partner

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

STATE OF Texas     )
COUNTY OF Midland     )

Before  me,  /s/ B. Ross, a Notary Public in and for the State  and  County
aforesaid, personally appeared H.H. Wommack, III, with whom I am personally
acquainted  (or  proved to me on the basis of satisfactory  evidence),  and
who,  upon  oath, acknowledged himself to be the attorney-in-fact  for  the
admitted  and  withdrawing Limited Partners, and as president of  Southwest
Royalties,  Inc.  for itself and as attorney-in-fact for the  admitted  and
withdrawing  Limited  Partners,  who  further  acknowledged  that   he   is
authorized  by  Southwest  Royalties, Inc., the Limited  Partners  and  the
Withdrawing  Limited Partners to execute this document  on  its  and  their
behalf.

Witness my hand and seal at office, on this the 16 day of July, 2001.

                    /s/ B. Ross
                    -----------------------------------
                    Notary Public

My commission expires:
08/30/01

<PAGE>


                        AMENDMENTS FOLLOW AS EX-99

<PAGE>