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

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

For the fiscal year ended December 31, 1999

                                    OR

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

For the transition period from                      to

Commission File Number 0-15411

                 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  50.   The  exhibit
index is found on page 45.

<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                       19

 9.   Changes in and Disagreements with Accountants
      on Accounting and Financial Disclosure                            34

                                 Part III

10.   Directors and Executive Officers of the Registrant                35

11.   Executive Compensation                                            37

12.   Security Ownership of Certain Beneficial Owners
      and Management                                                    37

13.   Certain Relationships and Related Transactions                    39

                                 Part IV

14.   Exhibits, Financial Statement Schedules and Reports
      on Form 8-K                                                       40

      Signatures                                                        44

<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  97  individuals,  together  with   certain
independent  consultants  used  on an "as-needed"  basis,  perform  various
services on behalf of the Partnership, including the selection of  oil  and
gas properties and the marketing of production from such properties.  H. H.
Wommack,  III,  a  stockholder, director, President and  Treasurer  of  the
Managing  General Partner, is also a general partner.  The Partnership  has
no employees.

Principal Products, Marketing and Distribution
The  Partnership has acquired and holds 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>

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

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

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

                                 Oil        Gas
                    1999         44%        56%
                    1998         37%        63%
                    1997         45%        55%

As  the table indicates, the Partnership's revenue is almost evenly divided
between its oil and gas 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. 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%.  Two purchasers accounted  for  49%  of  the
Partnership's  total  oil  and gas production during  1998:   Nustar  Joint
Venture  for  38%  and  Scurlock  Permian LLC  for  11%.   Five  purchasers
accounted for 67% of the Partnership's total oil and gas production  during
1997:   Nustar  Joint Venture  17%, Torch Operating Company  16%,  Scurlock
Permian  Corporation  13%, Aquila Southwest Pipeline  Corporation  11%  and
Enron  Oil  and  Transportation Incorporated 10%.  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,
1999,  there were 97 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, 1999, 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,
Crane,  Eastland,  Ector,  Fayette,  Gaines,  Glasscock,  Jim  Wells,  Lee,
Lipscomb,  Mitchell,  Nolan, Pecos, Reeves, Robertson,  Runnels,  Sterling,
Upton,  Ward  and Winkler Counties of Texas.  These properties  consist  of
various interests in approximately 172 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 1999, 1998 and 1997.

There  were no leases sold during 1999.  During 1998, 78 leases  were  sold
for   approximately  $61,000.   During  1997,  one  lease  was   sold   for
approximately $20,000.

<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           32,000  4,252,000
Tippet                to 100% net
Upton County,         profits
Texas                 interests

Enron/Rhoda           4/87 at 2%           41           96,000    372,000
Walker                to 100% net
Ward County,          profits
Texas                 interests

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

The  New York Mercantile Exchange price at December 31, 1999 of $25.60  was
used  as the beginning basis for the oil price.  Oil price adjustments from
$25.60  per  barrel were made in the individual evaluations to reflect  oil
quality,  gathering and transportation costs.  The results are  an  average
price received at the lease of $23.71 per barrel in the preparation of  the
reserve report as of January 1, 2000.

In  the  determination of the gas price, the New York  Mercantile  Exchange
price  at December 31, 1999 of $2.33 was used as the beginning basis.   Gas
price   adjustments  from  $2.33  per  Mcf  were  made  in  the  individual
evaluations to reflect BTU content, gathering and transportation costs  and
gas processing and shrinkage.  The results are an average price received at
the  lease of $2.23 per Mcf in the preparation of the reserve report as  of
January 1, 2000.


<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 1999.

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

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

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 1999 through the solicitation of proxies or otherwise.

<PAGE>

                                 Part II


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

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

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 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.  In 1998, 490 limited partner  units
were  tendered  to  and  purchased by the Managing General  Partner  at  an
average base price of $161.40 per unit.  In 1997, 940 limited partner units
were  tendered  to  and  purchased by the Managing General  Partner  at  an
average base price of $285.09 per unit.

Number of Limited Partner Interest Holders
As  of December 31, 1999 there were 826 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  monthly basis.  "Net Cash Flow" is defined  as  "the  cash
generated  by  the  Partnership's investments  in  producing  oil  and  gas
properties,  less  (i)  General and Administrative  Costs,  (ii)  Operating
Costs,  and  (iii) any reserves necessary to meet current  and  anticipated
needs  of  the  Partnership, as determined at the sole  discretion  of  the
Managing General Partner."

<PAGE>

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.  During 1998, distributions were made totaling $439,961,  with
$398,261  distributed to the limited partners and $41,700  to  the  general
partners.   For the year ended December 31, 1998, distributions  of  $19.91
per limited partner unit were made, based upon 20,000 limited partner units
outstanding.  During 1997, twelve monthly distributions were made  totaling
$929,000, with $836,100 distributed to the limited partners and $92,900  to
the  general partners.  For the year ended December 31, 1997, distributions
of  $41.81  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,
1999,  1998,  1997,  1996 and 1995 should be read in conjunction  with  the
financial statements included in Item 8:

                                    Years ended December 31,
                  ------------------------------------------------------------
                       1999       1998       1997       1996         1995
                       ----       ----       ----       ----         ----
Revenues          $  830,452     367,745    964,866 1,317,978    1,030,181

Net income (loss)    523,863    (49,492)    526,063   934,674      610,015

Partners' share
 of net income (loss):

 General partners     52,386     (4,949)     52,607    93,468       61,001

 Limited partners    471,477    (44,543)    473,456   841,206      549,014

Limited partners'
 net income (loss)
                   per unit         23.57     (2.23)     23.67        42.06
27.45

Limited partners'
 cash distributions
                   per unit         21.38      19.91     41.81        51.27
45.51

Total assets      $2,202,052   2,152,173  2,641,528 3,044,532    3,249,010

<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  several
workovers during 2000 and 2001 to enhance production.  The partnership  may
have  an  increase in production volumes for the years 2000 and  2001,  but
thereafter,  the  partnership  could  possibly  experience  the  historical
production decline of approximately 9% per year.

<PAGE>

Results of Operations

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

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

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                1999      1998   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil         $      16.98     12.38     37%
Average price per mcf of gas            $       2.31      1.89     22%
Oil production in barrels                     43,840    40,600      8%
Gas production in mcf                        406,660   453,300   (10%)
Income from net profits interests       $    823,002   362,778    127%
Partnership distributions               $    475,000   439,961      7%
Limited partner distributions           $    427,500   398,261      7%
Per unit distribution to limited partners          $     21.38      19.91
7%
Number of limited partner units               20,000    20,000

Revenues

The  Partnership's income from net profits interests increased to  $823,002
from $362,778 for the years ended December 31, 1999 and 1998, respectively,
an increase of 127%.  The principal factors affecting the comparison of the
years ended December 31, 1999 and 1998 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    increased  during the year ended December 31, 1999 as compared  to  the
    year ended December 31, 1998 by 37%, or $4.60 per barrel, resulting  in
    an  increase  of  approximately $186,800 in  income  from  net  profits
    interests.  Oil sales represented 44% of total oil and gas sales during
    the  year  ended December 31, 1999 as compared to 37% during  the  year
    ended December 31, 1998.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    increased during the same period by 22%, or $.42 per mcf, resulting  in
    an  increase  of  approximately $190,400 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
    $377,200.  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 increased approximately 3,240 barrels or 8% during  the
    year ended December 31, 1999 as compared to the year ended December 31,
    1998, resulting in an increase of approximately $55,000 in income  from
    net profits interests.

    Gas  production  decreased approximately 46,640 mcf or 10%  during  the
    same  period,  resulting  in  a decrease of approximately  $107,700  in
    income from net profits interests.

    The  net total decrease in income from net profits interests due to the
    change  in  production is approximately $52,700.  The increase  in  oil
    production  is due primarily to a successful workover performed  during
    the  beginning of 1999.  Production climbed during the middle  of  1999
    and  then  experienced a sharp decline.  The decrease in gas production
    is  due  primarily  to a significant gas well, which  experienced  down
    time,   but  after  a  major  workover  has  slowly  regained  previous
    production levels.

3.  Lease  operating  costs  and  production  taxes  were  13%  lower,   or
    approximately $134,000 less during the year ended December 31, 1999  as
    compared  to the year ended December 31, 1998.  The decrease  in  lease
    operating  costs  were primarily due to downtime  and  the  shut-in  of
    uneconomical wells.

Costs and Expenses

Total  costs and expenses decreased to $306,589 from $417,237 for the years
ended  December 31, 1999 and 1998, respectively, a decrease  of  27%.   The
decrease is primarily the result of lower depletion expense and 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
   12% or approximately $19,600 during the year ended December 31, 1999  as
   compared  to the year ended December 31, 1998.  The decrease of  general
   and  administrative  costs  were due in part  to  additional  accounting
   costs  incurred  in  1998  in relation to the  outsourcing  of  K-1  tax
   package  preparation  and a change in auditors requiring  opinions  from
   both  the  predecessors  and  successor  auditors.   Additionally,   the
   Managing  General  Partner in its effort to  cut  back  on  general  and
   administrative costs whenever and wherever possible was able  to  reduce
   the  cost  of  reserve  reports and K-1 tax package  preparation  during
   1999.

2. Depletion expense decreased to $156,000 for the year ended December  31,
   1999  from  $247,000  for the same period in 1998.   This  represents  a
   decrease  of  37%.  Depletion is calculated using the units  of  revenue
   method  of  amortization based on a percentage of current  period  gross
   revenues  to  total future gross oil and gas revenues, as  estimated  by
   the Partnership's independent petroleum consultants.

    A  contributing factor to the decrease in depletion expense between the
    comparative periods was the increase in the price of oil and  gas  used
    to determine the Partnership's reserves for January 1, 2000 as compared
    to  1999.   Another  contributing factor  was  due  to  the  impact  of
    revisions  of  previous estimates on reserves.  Revisions  of  previous
    estimates  can be attributed to the changes in production  performance,
    oil  and  gas  price and production costs.  The impact of the  revision
    would  have  decreased depletion expense approximately  $85,000  as  of
    December 31, 1998.

<PAGE>

Results of Operations

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

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

                                                  Year Ended     Percentage
                                                 December 31,     Increase
                                                1998      1997   (Decrease)
                                                ----      ----   ---------
Average price per barrel of oil         $      12.38     18.81   (34%)
Average price per mcf of gas            $       1.89      2.44   (23%)
Oil production in barrels                     40,600    50,100   (19%)
Gas production in mcf                        453,300   471,100    (4%)
Income from net profits interests       $    362,778   955,069   (62%)
Partnership distributions               $    439,961   929,000   (55%)
Limited partner distributions           $    398,261   836,100   (52%)
Per unit distribution to limited partners          $     19.91      41.81
(52%)
Number of limited partner units               20,000    20,000

Revenues

The  Partnership's income from net profits interests decreased to  $362,778
from $955,069 for the years ended December 31, 1998 and 1997, respectively,
a  decrease of 62%.  The principal factors affecting the comparison of  the
years ended December 31, 1998 and 1997 are as follows:

1.  The  average  price  for a barrel of oil received  by  the  Partnership
    decreased  during the year ended December 31, 1998 as compared  to  the
    year ended December 31, 1997 by 34%, or $6.43 per barrel, resulting  in
    a  decrease  of  approximately $322,100  in  income  from  net  profits
    interests.  Oil sales represented 37% of total oil and gas sales during
    the  year  ended December 31, 1998 as compared to 45% during  the  year
    ended December 31, 1997.

    The  average  price  for  an  mcf of gas received  by  the  Partnership
    decreased during the same period by 23%, or $.55 per mcf, resulting  in
    a  decrease  of  approximately $259,100  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
    $581,200.  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 9,500 barrels or 19% during the
    year ended December 31, 1998 as compared to the year ended December 31,
    1997, resulting in a decrease of approximately $117,600 in income  from
    net profits interests.

    Gas production decreased approximately 17,800 mcf or 4% during the same
    period, resulting in a decrease of approximately $33,600 in income from
    net profits interests.

    The  total  decrease in income from net profits interests  due  to  the
    change  in  production  is  approximately $151,200.   The  decrease  in
    production  is  in  relation  to downtime due  to  mechanical  problems
    uneconomical  to  repair  at  current  oil  prices  and  the  sale   of
    properties.

3.  Lease  operating  costs  and  production  taxes  were  12%  lower,   or
    approximately $142,200 less during the year ended December 31, 1998  as
    compared to the year ended December 31, 1997.

Costs and Expenses

Total  costs and expenses decreased to $417,237 from $438,803 for the years
ended  December  31, 1998 and 1997, respectively, a decrease  of  5%.   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 8%
    or  approximately $12,400 during the year ended December  31,  1998  as
    compared to the year ended December 31, 1997.

2. Depletion expense decreased to $247,000 for the year ended December  31,
   1998  from  $281,000  for the same period in 1997.   This  represents  a
   decrease  of  12%.  Depletion is calculated using the units  of  revenue
   method  of  amortization based on a percentage of current  period  gross
   revenues  to  total future gross oil and gas revenues, as  estimated  by
   the Partnership's independent petroleum consultants.

    A  contributing factor to the decrease in depletion expense between the
    comparative periods was the decrease in the price of oil and  gas  used
    to determine the Partnership's reserves for January 1, 1999 as compared
    to  1998.   Another  contributing factor  was  due  to  the  impact  of
    revisions  of  previous estimates on reserves.  Revisions  of  previous
    estimates  can be attributed to the changes in production  performance,
    oil  and  gas  price and production costs.  The impact of the  revision
    would  have  decreased depletion expense approximately  $29,000  as  of
    December 31, 1997.

<PAGE>

C.  Revenue and Distribution Comparison

Partnership net income (loss) for the years ended December 31,  1999,  1998
and  1997  was  $523,863 in 1999, $(49,492) in 1998 and $526,063  in  1997.
Excluding  the  effects  of depreciation, depletion and  amortization,  net
income for the years ended December 31, 1999, 1998 and 1997 would have been
$679,863, 197,508 and $807,063, respectively.  Correspondingly, Partnership
distributions  for the years ended December 31, 1999, 1998  and  1997  were
$475,000,  $439,961  and  $929,000, respectively.   These  differences  are
indicative  of the changes in oil and gas prices, production and properties
during 1999, 1998 and 1997.

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.   The  sources  for  the  1998
distributions  of  $439,961  were oil and gas operations  of  approximately
$339,200 and the change in oil and gas properties of approximately $98,400,
with  the  balance  from available cash on hand at  the  beginning  of  the
period.   The sources for the 1997 distributions of $929,000 were  oil  and
gas  operations  of approximately $893,500 and the change in  oil  and  gas
properties  of approximately $10,800, with the balance from available  cash
on hand at the beginning of the period.

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.  Total distributions during  the  year  ended
December  31, 1998 were $439,961 of which $398,261 was distributed  to  the
limited  partners  and  $41,700  to the general  partners.   The  per  unit
distribution to limited partners during the same period was $19.91.   Total
distributions  during  the year ended December 31, 1997  were  $929,000  of
which  $836,100 was distributed to the limited partners and $92,900 to  the
general partners.  The per unit distribution to limited partners during the
same period was $41.81.

Since  inception of the Partnership, cumulative monthly cash  distributions
of  $15,151,459 have been made to the partners.  As of December  31,  1999,
$13,651,782  or  $682.59 per limited partner unit, has been distributed  to
the   limited   partners,  representing  a  137%  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 $616,600  in
1999 compared to $339,200 in 1998 and approximately $893,500 in 1997.   The
primary  source  of  the  1999  cash flow  from  operating  activities  was
profitable operations.

The  Partnership had no cash flows from investing activities in 1999.  Cash
flows  provided by investing activities were approximately $98,400 in  1998
and approximately $10,800 in 1997.

Cash flows used in financing activities were approximately $474,000 in 1999
compared to $439,900 in 1998 and approximately $929,000 in 1997.  The  only
use in financing activities was the distributions to partners.

As  of  December  31, 1999, the Partnership had approximately  $353,100  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 - Managing General Partner
The  Managing General Partner has a highly leveraged capital structure with
over  $35.1  million principal and $17.5 million interest payments  due  in
2000  on  its  debt  obligations.  Due to the severely depressed  commodity
prices  experienced  during the last quarter of 1997, throughout  1998  and
continuing through the second quarter of 1999 the Managing General  Partner
is  experiencing difficulty in generating sufficient cash flow to meet  its
obligations  and sustain its operations.  The Managing General  Partner  is
currently  in  the  process  of renegotiating  the  terms  of  its  various
obligations  with its creditors and/or attempting to seek  new  lenders  or
equity  investors.   Additionally,  the  Managing  General  Partner   would
consider disposing of certain assets in order to meet its obligations.

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

Information Systems for the Year 2000
The  year  2000  issue  referred to the risk of disruptions  of  operations
caused  by  the  failure of computer-controlled systems, including  systems
used  by  third  parties, to properly recognize date sensitive  information
when  the  year changed from 1999 to 2000.  During the year ended  December
31, 1999, the Managing General Partners data processing subsidiary, Midland
Southwest  Software, Inc., installed new software as part  of  an  on-going
project  to upgrade its financial and management information systems.   The
cost  of  upgrading the software occurred in the normal course  of  Midland
Southwest  Software's  business and was not  material  to  the  results  of
operations or financial condition of the Partnership.

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

<PAGE>

Item 8.   Financial Statements and Supplementary Data

                      Index to Financial Statements

                                                                       Page

Independent Auditors Report                                             20

Balance Sheets                                                          21

Statements of Operations                                                22

Statement of Changes in Partners' Equity                                23

Statements of Cash Flows                                                24

Notes to Financial Statements                                           26

<PAGE>










                        INDEPENDENT AUDITORS REPORT

The Partners
Southwest 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, 1999 and  1998,
and  the related statements of operations, changes in partners' equity  and
cash  flows for each of the years in the three- year period ended  December
31,  1999.   These  financial  statements are  the  responsibility  of  the
Partnership's management.  Our responsibility is to express an  opinion  on
these financial statements based on our audits.

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

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








                                                  KPMG LLP



Midland, Texas
March 10, 2000

<PAGE>


                 Southwest Royalties, Inc. Income Fund VI
                    (a Tennessee limited partnership)
                              Balance Sheets
                        December 31, 1999 and 1998


                                                      1999          1998
                                                      ----          ----
  Assets

Current assets:
 Cash and cash equivalents                   $       181,112       38,539
 Receivable from Managing General Partner            173,306      110,000

---------                                    ---------
                                                 Total    current    assets
354,418                                      148,539

---------                                    ---------
Oil and gas properties - using the full-
 cost method of accounting                         8,426,634    8,426,634
  Less accumulated depreciation,
                                               depletion  and  amortization
6,579,000                                    6,423,000

---------                                    ---------
                                              Net  oil  and gas  properties
1,847,634                                    2,003,634

---------                                    ---------
                                                                          $
2,202,052                                    2,152,173

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

Current liability - distribution payable     $         1,317          301

---------                                    ---------
Partners' equity:
 General partners                                  (634,496)    (639,382)
 Limited partners                                  2,835,231    2,791,254

---------                                    ---------
                                                Total    partners'   equity
2,200,735                                    2,151,872

---------                                    ---------
                                                                          $
2,202,052                                    2,152,173

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






















                  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, 1999, 1998 and 1997


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

Income from net profits interests         $    823,002   362,778  955,069
Interest                                         7,450     4,967    9,797
                                                                    -------
---------                                 ---------
                                                                    830,452
367,745                                   964,866
                                                                    -------
---------                                 ---------
  Expenses

General and administrative                     150,589   170,237  157,803
Depreciation, depletion and amortization       156,000   247,000  281,000
                                                                    -------
---------                                 ---------
                                                                    306,589
417,237                                   438,803
                                                                    -------
---------                                 ---------
Net income (loss)                         $    523,863  (49,492)  526,063
                                                                    =======
=========                                 =========
Net income (loss) allocated to:

 Managing General Partner                 $     47,147   (4,454)   47,346
                                                                    =======
=========                                 =========
 General partner                          $      5,239     (495)    5,261
                                                                    =======
=========                                 =========
 Limited partners                         $    471,477  (44,543)  473,456
                                                                    =======
=========                                 =========
  Per limited partner unit                $      23.57     (2.23)   23.67
                                                                    =======
=========                                 =========


























                  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, 1999, 1998 and 1997


                                            General    Limited
                                            Partners   Partners    Total
                                            --------   --------    -----
Balance at December 31, 1996            $ (552,440)   3,596,702 3,044,262

 Net income                                  52,607     473,456   526,063

 Distributions                             (92,900)   (836,100) (929,000)
                                                                   --------
----------                              ----------
Balance at December 31, 1997              (592,733)   3,234,058 2,641,325

 Net income (loss)                          (4,949)    (44,543)  (49,492)

 Distributions                             (41,700)   (398,261) (439,961)
                                                                   --------
----------                              ----------
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
                                                                   ========
==========                              ==========


























                  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, 1999, 1998 and 1997


                                                             1999      1998
1997
                                                             ----      ----
----
Cash flows from operating activities:

 Cash received from net profits interests $    766,709   489,7681,041,521
 Cash paid to Managing General Partner
  for administrative fees and general
                                            and   administrative   overhead
(157,603)                                 (155,489)(157,803)
 Interest received                               7,450     4,967    9,797
                                                                   --------
---------                                 ---------
   Net  cash provided by operating activities              616,556  339,246
893,515
                                                                   --------
---------                                 ---------
Cash provided by investing activities:

 Sale of oil and gas properties                      -    98,437   10,833
                                                                   --------
---------                                 ---------
Cash used in financing activities:

 Distributions to partners                   (473,983) (439,863)(929,067)
                                                                   --------
---------                                 ---------

Net decrease in cash and cash equivalents      142,573   (2,180) (24,719)

 Beginning of year                              38,539    40,719   65,438
                                                                   --------
---------                                 ---------
 End of year                              $    181,112    38,539   40,719
                                                                   ========
=========                                 =========


(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, 1999, 1998 and 1997


                                                             1999      1998
1997
                                                             ----      ----
----
Reconciliation of net income (loss) to net
 cash provided by operating activities:

Net income (loss)                         $    523,863  (49,492)  526,063

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

   Depreciation, depletion and amortization               156,000   247,000
281,000
  (Increase) decrease in receivables          (56,294)   126,990   86,452
  (Decrease) increase in payables              (7,013)    14,748        -
                                                                    -------
---------                                 -------
Net cash provided by operating activities $    616,556   339,246  893,515
                                                                    =======
=========                                 =======

Supplemental schedule of noncash investing
  and financing activities:

  Sale of oil and gas property included in
     receivable from Managing General Partner         $         -         -
20,000
                                                           ================
=======































                  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.  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, 1999, 1998  and  1997,
    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.

<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.  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, 1999 and 1998,  the
    Partnership  was over produced by 1,429 and 1,596 mcf of  gas.   As  of
    December 31, 1997, the Partnership was under produced by 16,527 mcf  of
    gas, respectively.

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

    In   accordance  with  the  requirements  of  Statement  of   Financial
    Accounting  Standards  No.  109, "Accounting  for  Income  Taxes",  the
    Partnership's tax basis in its net oil and gas properties  at  December
    31,  1999  and 1998 is $981,811 and $892,768, respectively,  less  than
    that  shown  on  the  accompanying Balance Sheets  in  accordance  with
    generally accepted accounting principles.

<PAGE>

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

                      Notes to Financial Statements


2.  Summary of Significant Accounting Policies - continued

    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,  1999, 1998 and 1997, there were  20,000  limited
    partner units outstanding held by 826, 848 and 876 partners.

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

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

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

3.  Liquidity - Managing General Partner
    The  Managing General Partner has a highly leveraged capital  structure
    with  over $35.1 million principal and $17.5 million interest  payments
    due  in  2000  on its debt obligations.  Due to the severely  depressed
    commodity  prices  experienced  during  the  last  quarter   of   1997,
    throughout 1998 and continuing through the second quarter of  1999  the
    Managing  General  Partner  is experiencing  difficulty  in  generating
    sufficient   cash  flow  to  meet  its  obligations  and  sustain   its
    operations.   The Managing General Partner is currently in the  process
    of  renegotiating  the  terms  of  its  various  obligations  with  its
    creditors  and/or  attempting to seek new lenders or equity  investors.
    Additionally, the Managing General Partner would consider disposing  of
    certain assets in order to meet its obligations.

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

<PAGE>

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

                      Notes to Financial Statements


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, 1999, the Partnership has not been fined, cited  or
    notified of any environmental violations and management is not aware of
    any  unasserted  violations which would have a material adverse  effect
    upon capital expenditures, earnings or the competitive position in  the
    oil  and  gas  industry.  However, the Managing  General  Partner  does
    recognize by the very nature of its business, material costs  could  be
    incurred  in  the  near  term  to  bring  the  Partnership  into  total
    compliance.  The amount of such future expenditures is not 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 is usual in the industry and as provided
    for in the operating agreement for each respective oil and gas property
    in  which  the  Partnership has an interest, the operator  is  paid  an
    amount  for  administrative  overhead attributable  to  operating  such
    properties, with such amounts to Southwest Royalties, Inc. as  operator
    approximating  $105,400, $128,200 and $125,000,  for  the  years  ended
    December  31,  1999,  1998 and 1997, respectively.   In  addition,  the
    Managing General Partner and certain officers and employees may have an
    interest  in  some  of  the properties 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
    $75,500,  $16,200  and $4,000, for the years ended December  31,  1999,
    1998  and 1997, respectively, and the Managing General Partner believes
    that  these  costs  are  comparable to  similar  charges  paid  by  the
    Partnership to unrelated third parties.

    Southwest  Royalties,  Inc., the Managing  General  Partner,  was  paid
    $144,000  during  1999,  1998 and 1997, as an  administrative  fee  for
    indirect general and administrative overhead expenses.

    Receivables  from  Southwest  Royalties,  Inc.,  the  Managing  General
    Partner,  of approximately $173,300 and $110,000 are from oil  and  gas
    production,  net of lease operating costs and production taxes,  as  of
    December 31, 1999 and 1998, respectively.

    In  addition, a director and officer of the Managing General Partner is
    a partner in a law firm, with such firm providing legal services to the
    Partnership  approximating $900, $900 and $1,300, for the  years  ended
    December 31, 1999, 1998 and 1997, 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.  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%.  Two purchasers accounted  for
    49%  of  the  Partnership's total oil and gas production  during  1998:
    Nustar Joint Venture 38% and Scurlock Permian LLC 11%.  Five purchasers
    accounted  for  67% of the Partnership's total oil and  gas  production
    during 1997:  Nustar Joint Venture  17%, Torch Operating Company   16%,
    Scurlock Permian Corporation 13%, Aquila Southwest Pipeline Corporation
    11%  and Enron Oil and Transportation Incorporated 10%.  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, 1997                                677,000       5,775,000

      Revisions of previous estimates            (106,000)     (1,452,000)
      Production                                  (50,000)       (471,000)
      Sale of minerals in place                   (11,000)               -
                                                   -------       ---------
    December 31, 1997                              510,000       3,852,000

      Revisions of previous estimates            (204,000)       1,802,000
      Production                                  (41,000)       (453,000)
      Sale of minerals in place                    (9,000)       (118,000)
                                                   -------       ---------
    December 31, 1998                              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
                                                   =======       =========
    Proved developed reserves -

    December 31, 1997                              428,000       3,544,000
                                                   =======       =========
    December 31, 1998                              216,000       4,891,000
                                                   =======       =========
    December 31, 1999                              385,000       5,398,000
                                                   =======       =========



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

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

    The  New York Mercantile Exchange price at December 31, 1999 of  $25.60
    was  used  as  the  beginning  basis for  the  oil  price.   Oil  price
    adjustments  from  $25.60  per  barrel  were  made  in  the  individual
    evaluations to reflect oil quality, gathering and transportation costs.
    The  results are an average price received at the lease of  $23.71  per
    barrel in the preparation of the reserve report as of January 1, 2000.

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

                      Notes to Financial Statements


7.  Estimated Oil and Gas Reserves (unaudited) - continued
    In the determination of the gas price, the New York Mercantile Exchange
    price  at  December 31, 1999 of $2.33 was used as the beginning  basis.
    Gas  price  adjustments from $2.33 per Mcf were made in the  individual
    evaluations to reflect BTU content, gathering and transportation  costs
    and  gas  processing and shrinkage.  The results are an  average  price
    received  at  the  lease  of $2.23 per Mcf in the  preparation  of  the
    reserve report as of January 1, 2000.

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

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

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

    Because  the  Partnership does not engage in drilling  activities,  the
    development  of  proved undeveloped reserves 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, 1999, 1998 and 1997  is
    presented below:

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

     Future cash inflows, net of
                                        production and development
      costs                             $ 14,581,000  7,278,000  9,969,000
     10% annual discount for
                                        estimated timing of cash
      flows                                6,733,000  3,397,000  3,406,000
                                           --------- ---------- ----------
     Standardized measure of
                                        discounted future net cash
      flows                             $  7,848,000  3,881,000  6,563,000
                                           ========= ========== ==========

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

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

     Sales of oil and gas produced,
                                       net of production costs $  (823,000)
(362,000)                             (955,000)
     Changes in prices and production
       costs                              2,271,000 (1,423,000)(7,159,000)
     Changes in estimated future development
                                       cost            (122,000)   (29,000)
-
     Changes of production rates
       (timing) and others                 (25,000) (1,736,000)  1,053,000
     Sales of minerals in place                   -   (131,000)   (15,000)
     Revisions of previous
                                       quantities estimates       2,278,000
343,000                               (1,968,000)
     Accretion of discount                  388,000     656,000  1,419,000
     Discounted future net
                                      cash flows -
      Beginning of year                   3,881,000   6,563,000 14,188,000
                                         ----------  ---------- ----------
      End of year                     $   7,848,000   3,881,000  6,563,000
                                         ==========  ========== ==========

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

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

          None

<PAGE>

                                 Part III


Item 10.  Directors and Executive Officers of the Registrant

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

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

H. Allen Corey              43          Secretary and Director

Bill E. Coggin                          45     Vice  President  and   Chief
                                        Financial Officer

J. Steven Person            41          Vice President, Marketing

Paul L. Morris              58          Director

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

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

<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.D.A. from Houston Baptist University in 1987.

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

Key Employees

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

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


<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 1999, 1998 and 1997 as an annual  administrative
fee.

Item 12.  Security Ownership of Certain Beneficial Owners and Management

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

The  Managing  General Partner owns a nine percent interest  as  a  general
partner.   Through repurchase offers to the limited partners, the  Managing
General  Partner  also owns 4,029 limited partner units,  a  20.2%  limited
partner  interest.  The Managing General Partners total percentage interest
ownership in the Partnership is 27.1%.

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

<PAGE>

                                                   Amount and
                                                   Nature of      Percent
                     Name and Address of           Beneficial        of
  Title of Class       Beneficial Owner            Ownership       Class
-------------------  ---------------------------  ---------------  -------
Limited Partnership  Southwest Royalties, Inc.    Directly Owns     20.2%
                      Interest                     Managing General Partner
4,029 Units
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  H. H. Wommack, III           Indirectly Owns   20.2%
                      Interest                      Chairman of the  Board,
4,029 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   20.2%
                     Interest                     Secretary and Director of
4,029 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     633 Chestnut Street
                     Chattanooga, TN  37450-1800

Limited Partnership  Bill E. Coggin               Indirectly Owns   20.2%
                     Interest                     Vice President and CFO of
4,029 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  J. Steven Person             Indirectly Owns   20.2%
                     Interest                     Vice President, Marketing
4,029 Units
                     Southwest Royalties, Inc.,
                     the Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

Limited Partnership  Paul L. Morris               Indirectly Owns   20.2%
                      Interest                      Director  of  Southwest
4,029 Units
                     Royalties, Inc., the
                     Managing General
                     Partner
                     407 N. Big Spring Street
                     Midland, TX  79701

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

<PAGE>
Item 13.  Certain Relationships and Related Transactions

In   1999,   the   Managing  General  Partner  received  $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 $105,400  for  administrative
overhead attributable to operating such properties during 1999.

Certain  subsidiaries or affiliates of the Managing General Partner perform
various  oilfield services for properties in which the Partnership owns  an
interest.   Such  services aggregated approximately $75,500  for  the  year
ended December 31, 1999.

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  1999   were
approximately $900, 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.

                  27 Financial Data Schedule

                  99 Limited Partners as of February 25, 1999
                     Limited Partners as of July 27, 1999

               (b)    Reports on Form 8-K

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

<PAGE>

                                Signatures


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


                          Southwest 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:  March 31, 2000


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


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


Date:  March 31, 2000


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


Date:  March 31, 2000

<PAGE>

                              Exhibit Index


Item No.     Description                                           Page No.

14(a)(3)       Exhibit  4(bb):  Twenty  Seventh  Amendment  to  Certificate
46
             and Agreement of Limited Partnership of Southwest
             Royalties, Inc. Income Fund VI, dated as of
             February 25, 1999.

             Exhibit 4 (cc): Twenty Eighth Amendment to Certificate      48
             and Agreement of Limited Partnership of Southwest
             Royalties, Inc. Income Fund VI, dated as of
             July 27, 1999.

<PAGE>

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

         TWENTY-SEVENTH 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 Twenty-seventh 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, 1998, 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 TENNESSEE      )
COUNTY OF HAMILTON      )

Before  me, /s/ Suetta M. Morgan, 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 25th day of February  25,
1999.

                    /s/ Suetta M. Morgan
                    -----------------------------------
                    Notary Public



<PAGE>

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

         TWENTY-EIGHTH 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 Twenty-eighth 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  27th
day  of  July,  1999,  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/ Paula Dillard, 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 27th day of July, 1999.

                    /s/ Paula Dillard
                    -----------------------------------
                    Notary Public



<PAGE>

                        AMENDMENTS FOLLOW AS EX-99

<PAGE>