<PAGE>

                               FORM 10-K

                  SECURITIES AND EXCHANGE COMMISSION
                        Washington, D.C.  20549

           Annual Report Pursuant to Section 13 or 15(d) of
                  the Securities Exchange Act of 1934

For the fiscal year ended December 31, 1995

Commission File Number 0-12052

                    DYCO OIL AND GAS PROGRAM 1983-1
                        (A LIMITED PARTNERSHIP)
        (Exact name of registrant as specified in its charter)

           Minnesota                       41-1451945
(State or other jurisdiction of         (I.R.S. Employer
incorporation or organization)       Identification Number)

         Samson Plaza
   Two West Second Street
        Tulsa, Oklahoma                       74103
     (Address of principal                 (Zip Code)
      executive offices)

Registrant's telephone number, including area code: (918) 583-1791

Securities registered pursuant to Section 12(b) of the Act:  None.

Securities registered pursuant to Section 12(g) of the Act:  
     Units of limited partnership interest

     Indicate by  check mark whether the registrant  (1) has filed all
reports required to be filed by  Section 13 or 15(d) of the Securities
Exchange Act  of 1934  during the  preceding 12  months  (or for  such
shorter period that the registrant was required to file such reports),
and (2) has been  subject to the 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 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.  
Yes   X   No        (Disclosure is contained herein)
   -----    -----

     The  units  of  limited  partnership  are  not  publicly  traded,
therefore, registrant cannot compute the aggregate market value of the
voting units held by non-affiliates of the registrant.

     DOCUMENTS INCORPORATED BY REFERENCE:  None.
<PAGE>
<PAGE>
                               FORM 10-K

                    DYCO OIL AND GAS PROGRAM 1983-1
                   (a Minnesota limited partnership)


                           TABLE OF CONTENTS



PART I  . . . . . . . . . . . . . . . . . . . . . . . . . . . . .    1
     ITEM 1.   BUSINESS . . . . . . . . . . . . . . . . . . . . .    1
     ITEM 2.   PROPERTIES . . . . . . . . . . . . . . . . . . . .    5
     ITEM 3.   LEGAL PROCEEDINGS  . . . . . . . . . . . . . . . .   10
     ITEM 4.   SUBMISSION OF MATTERS TO A VOTE OF LIMITED
               PARTNERS . . . . . . . . . . . . . . . . . . . . .   10

PART II . . . . . . . . . . . . . . . . . . . . . . . . . . . . .   10
     ITEM 5.   MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP
               UNITS AND RELATED LIMITED PARTNER MATTERS  . . . .   10
     ITEM 6.   SELECTED FINANCIAL DATA  . . . . . . . . . . . . .   12
     ITEM 7.   MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
               CONDITION AND RESULTS OF OPERATIONS  . . . . . . .   13
     ITEM 8.   FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA  . . .   17
     ITEM 9.   CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
               ACCOUNTING AND FINANCIAL DISCLOSURE  . . . . . . .   28

PART III  . . . . . . . . . . . . . . . . . . . . . . . . . . . .   28
     ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE
               REGISTRANT . . . . . . . . . . . . . . . . . . . .   28
     ITEM 11.  EXECUTIVE COMPENSATION . . . . . . . . . . . . . .   30
     ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL
               OWNERS AND MANAGEMENT  . . . . . . . . . . . . . .   34
     ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS . .   35

PART IV . . . . . . . . . . . . . . . . . . . . . . . . . . . . .   36
     ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND
               REPORTS ON FORM 8-K  . . . . . . . . . . . . . . .   36
     SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . .   38


                                  ii
<PAGE>
<PAGE>
                                PART I


ITEM 1.   BUSINESS

     General

     The Dyco  Oil and  Gas Program  1983-1  Limited Partnership  (the
"Program")  is   a  Minnesota  limited  partnership   engaged  in  the
production  of oil  and  gas.   The  Program commenced  operations  on
July 1, 1983  with the primary  financial objective  of investing  its
limited partners'  subscriptions  in  the  drilling  of  oil  and  gas
prospects and then  distributing to its limited partners all available
cash flow  from the  Program's on-going  production operations.   Dyco
Petroleum  Corporation ("Dyco") serves  as the General  Partner of the
Program.  See "Item 2. Properties" for  a description of the Program's
reserves and properties.

     The limited  partnership agreement for the  Program provides that
limited partners are allocated  99% of all Program costs  and revenues
and that  Dyco, as  General Partner,  is allocated  1% of  all Program
costs  and  revenues.    Included  in  such  costs  is  the  Program's
reimbursement to Dyco  of the Program's proportionate  share of Dyco's
geological, engineering, and general and administrative expenses.

     Dyco  serves  as  General  Partner of  34  limited  partnerships,
including  the Program.  Dyco  is a wholly-owned  subsidiary of Samson
Natural  Gas  Company, which  is a  wholly-owned subsidiary  of Samson
Investment  Company.    Samson  Investment  Company  and  its  various
corporate subsidiaries,  including  Dyco, (collectively,  the  "Samson
Companies")  are  engaged in  the  production and  development  of and
exploration for oil and gas reserves and the acquisition and operation
of producing properties.  At  December 31, 1995, the Samson  Companies
owned interests in approximately  18,000 oil and gas wells  located in
19 states  of the  U.S. and  3 provinces of  Canada.   At December 31,
1995, the  Samson Companies operated  approximately 3,100 oil  and gas
wells  located in  15  states  of the  U.S.,  2  provinces of  Canada,
Venezuela, and Russia.

     As a limited partnership, the Program has no officers, directors,
or employees.   It  relies instead  on the personnel  of Dyco  and the
other  Samson Companies.  As of February 1, 1996, the Samson Companies
employed  approximately  830 persons.    No employees  are  covered by
collective  bargaining agreements,  and management  believes that  the
Samson Companies provide a sound  employee relations environment.  For
information  regarding  the  executive  officers of  Dyco,  see  "Item
10. Directors and Executive Officers of the Registrant."


                                   1
<PAGE>
<PAGE>
     Dyco's and the Program's  principal place of business  is located
at  Samson Plaza, Two West  Second Street, Tulsa,  Oklahoma 74103, and
their telephone number is (918) 583-1791 or (800) 535-1791.


     Funding

     Although the Program's partnership agreement permits the  Program
to  incur  borrowings,  the  Program's  operations  and  expenses  are
currently funded out of the Program's revenues from oil and gas sales.
Dyco may, but is not required to, advance funds to the Program for the
same purposes for which Program borrowings are authorized.


     Principal Products Produced and Services Rendered

     The Program's  sole business is the development and production of
oil and natural gas with a concentration on natural gas.   The Program
does not hold any patents, trademarks, licenses, or concessions and is
not a party  to any government contracts.  The  Program has no backlog
of orders  and  does  not  participate  in  research  and  development
activities.  The  Program is not  presently encountering shortages  of
oilfield  tubular goods,  compressors, production  material, or  other
equipment.


     Oil, Gas, and Environmental Control Regulations

     Regulation of Production Operations -- The production of  oil and
gas is subject  to extensive  federal and state  laws and  regulations
governing a  wide  variety  of matters,  including  the  drilling  and
spacing of wells,  allowable rates of production,  prevention of waste
and pollution, and protection of the environment.   In addition to the
direct costs borne in complying with such regulations, operations  and
revenues  may be impacted to the extent that certain regulations limit
oil and gas production to below economic levels.

     Regulation  of Sales and Transportation of Oil and Natural Gas --
Sales of  crude oil and condensate  are made by the  Program at market
prices and are not subject to price controls.  The sale of natural gas
may  be  subject  to both  federal  and  state  laws and  regulations,
including,  but  not limited  to, the  Natural  Gas Act  of  1938 (the
"NGA"),  the  Natural  Gas  Policy  Act  of  1978  (the  "NGPA"),  and
regulations promulgated  by the  Federal Energy  Regulatory Commission
(the  "FERC")  under the  NGA,  the NGPA,  and  other  statutes.   The
provisions of  the  NGA  and the  NGPA,  as well  as  the  regulations
thereunder, are complex and affect all who produce, resell, transport,
or  purchase natural gas,  including the Program.   Although virtually
all of the Program's gas production is not subject to price regulation,

                                   2
<PAGE>
the  NGA,   NGPA,  and   FERC  regulations   affect  the availability
of  gas transportation services  and the  ability of  gas consumers
to continue to purchase or use gas at current levels.  Accordingly, 
such  regulations  may  have a  material  effect  on  the Program's
operations and projections of  future oil and gas production and
revenues.

     Future  Legislation  -- Legislation  affecting  the  oil and  gas
industry  is  under  constant  review for  amendment  or  expansion.  
Because  such   laws  and   regulations  are  frequently   amended  or
reinterpreted, management is unable  to predict what additional energy
legislation may  be proposed or enacted or  the future cost and impact
of complying with existing or future regulations.

     Regulation  of the  Environment --  The Program's  operations are
subject to numerous  laws and regulations  governing the discharge  of
materials into the environment  or otherwise relating to environmental
protection.  Compliance with such  laws and regulations, together with
any penalties resulting from noncompliance therewith, may increase the
cost of the Program's  operations or may affect the  Program's ability
to complete,  in  a timely  fashion,  existing or  future  activities.
Management  anticipates   that  various  local,   state,  and  federal
environmental control agencies  will have an increasing  impact on oil
and gas operations. 


     Significant Customers

     Purchases of gas by Premier Gas Company ("Premier") accounted for
approximately 98.0% of the  Program's oil and gas revenues  during the
year ended December 31, 1995.   Premier was an affiliate of Dyco until
December  6, 1995.   See  "Item 11. Executive  Compensation."   In the
event of interruption of purchases by this significant customer or the
cessation  or   material   change  in   availability  of   open-access
transportation by the Program's pipeline transporters, the Program may
encounter difficulty in marketing its  gas and in maintaining historic
sales  levels.   Alternative  purchasers  or transporters  may  not be
readily available.

     The Program's  principal customers  for crude oil  production are
refiners and other  companies which have pipeline  facilities near the
producing properties of the Program.  In the event pipeline facilities
are  not  conveniently available  to  production areas,  crude  oil is
usually trucked by purchasers to storage facilities. 


                                   3
<PAGE>
<PAGE>
     Competition and Marketing

     The  oil and  gas industry  is highly  competitive, with  a large
number of  companies and  individuals engaged  in the exploration  and
development of oil and gas properties.   The ability of the Program to
produce  and market  oil  and gas  profitably depends  on a  number of
factors  that are beyond  the control of  the Program.   These factors
include worldwide  political instability (especially  in oil-producing
regions), the  supply and price of foreign imports of oil and gas, the
level  of  consumer product  demand  (which is  heavily  influenced by
weather  patterns), government  regulations and  taxes, the  price and
availability of alternative fuels,  the overall economic  environment,
and  the availability  and capacity  of transportation  and processing
facilities.    The  effect  of  these  factors  cannot  be  accurately
predicted or anticipated.

     As a  general rule,  in recent  years,  worldwide oil  production
capacity  and gas production capacity  in certain areas  of the United
States exceeded  demand and resulted in a decline in the average price
of oil and gas in  the United States.   During the later part of  1994
and  1995, however, average oil prices in the United States increased.
Oil prices increased  from approximately $16.50  per barrel at  Decem-
ber 31, 1994 to approximately $18.50  per barrel at December 31, 1995.
Management  is  unable  to  predict  whether  future oil  prices  will
(i) stabilize, (ii) increase, or (iii) decrease.

     Gas  sales contract prices  have generally declined significantly
since the mid-1980s due to a number of factors, including a nationwide
surplus  of gas and increased competition.   Competition has increased
among United  States gas marketers due to the gas surplus, the partial
deregulation  of gas prices, the conversion by major pipelines to open
access transportation, and  the lack of strong  residential demand for
natural  gas during  the winter  months for  the last  few years  as a
result of  warm winters in much  of the United States.   However, spot
gas  prices in the areas where the Program's gas is marketed increased
during the later part of 1995
compared to  prices received in the  later part of 1994  and the first
several months of 1995.  

     Substantially all of the Program's natural gas reserves are being
sold in  the "spot market."   Due to the highly  competitive nature of
the  spot  market,  prices on  the  spot  market are  subject  to wide
seasonal and regional  pricing fluctuations.   In addition, such  spot
market sales are generally short-term in nature and are dependent upon
the obtaining of transportation services provided by pipelines.  

                                   4
<PAGE>
<PAGE>
     The Program's spot gas  prices increased from approximately $1.67
per  Mcf  at  December 31, 1994  to  approximately  $2.00  per Mcf  at
December 31, 1995.  Such prices were on an MMBTU basis and differ from
the  prices actually received by the Program due to transportation and
marketing  costs,  BTU adjustments,  and  regional  price and  quality
differences.  Future prices will likely be different from  (and may be
lower  than) the prices in effect on  December 31, 1995.  In many past
years,  year-end prices  have tended to  be higher, and  in some cases
significantly higher, than the  yearly average price actually received
by the Program for at least  the year following the year-end valuation
date.  Management is unable to predict whether  future gas prices will
(i) stabilize, (ii) increase, or (iii) decrease.    


     Insurance Coverage 

     The  Program is  subject  to all  of  the risks  inherent in  the
exploration for  and production  of oil  and gas,  including blowouts,
pollution,  fires,  and  other  casualties.    The  Program  maintains
insurance  coverage as  is customary  for entities  of a  similar size
engaged in operations  similar to that of the Program,  but losses can
occur  from  uninsurable risks  or in  amounts  in excess  of existing
insurance coverage.   The occurrence of  an event which  is not  fully
covered  by  insurance could  have a  material  adverse effect  on the
financial position and results of operations.  


ITEM 2.   PROPERTIES

     Well Statistics

     The  following  table sets  forth the  numbers  of gross  and net
productive wells of the Program as of December 31, 1995.

                          Well Statistics(1)

                        As of December 31, 1995

              Gross productive wells(2):
                Oil                              1
                Gas                             22
                                                --
                  Total                         23

              Net productive wells(3):
                Oil                            .08
                Gas                           3.33
                                              ----
                  Total                       3.41

----------

                                   5
<PAGE>
<PAGE>
(1)  The designation of a well as an  oil well or gas well is made  by
     Dyco based on the relative amount of oil and gas reserves for the
     well.   Regardless  of a  well's oil  or gas designation,  it may
     produce oil, gas, or both oil and gas.
(2)  As used throughout this  Annual Report, "Gross Well" refers  to a
     well in which a working  interest is owned.  The number  of gross
     wells is the total number of wells in which a working interest is
     owned.
(3)  As used throughout this  Annual Report, "Net Well" refers  to the
     sum  of  the fractional  working interests  owned in  gross wells
     expressed as whole numbers and fractions thereof.  For example, a
     15% leasehold interest in  a well represents one Gross  Well, but
     0.15 Net Well.


     Drilling Activities  

     The Program participated  in no drilling activities  for the year
ended December 31, 1995.  


     Oil and Gas Production, Revenue, and Price History 

     The following  table sets  forth  certain historical  information
concerning the oil (including condensates) and natural gas production,
net of  all royalties,  overriding royalties,  and  other third  party
interests, of  the Program, revenues attributable  to such production,
and certain price and cost information.  

                          Net Production Data

                                      Year Ended December 31,
                                 --------------------------------
                                   1995       1994        1993
                                 --------  ----------  ----------
Production:
  Oil (Bbls)(1)                       696       1,404       1,068
  Gas (Mcf)(2)                    485,174     691,469     958,106

Oil and gas sales:
  Oil                            $ 12,133  $   21,809  $   18,047
  Gas                             584,600   1,081,000   1,737,828
                                  -------   ---------   ---------

    Total                        $596,733  $1,102,809  $1,755,875
                                  =======   =========   =========

                                   6
<PAGE>
<PAGE>
Total direct operating
  expenses                       $284,335  $  317,403  $  332,084

Direct operating expenses
  as a percentage of oil
  and gas sales                     47.6%       28.8%       18.9%

Average sales price:
  Per barrel of oil                $17.43      $15.53      $16.90
  Per Mcf of gas                     1.20        1.56        1.81

Direct operating expenses
  per equivalent Mcf of gas(3)     $  .58      $  .45      $  .34

----------

(1)  As used throughout this  Annual Report, "Bbls" refers to  barrels
     of  42 U.S. gallons and  represents the basic  unit for measuring
     the production of crude oil and condensate oil.
(2)  As  used throughout this Annual Report, "Mcf" refers to volume of
     1,000  cubic feet  under  prescribed conditions  of pressure  and
     temperature  and  represents the  basic  unit  for measuring  the
     production of natural gas.
(3)  Oil production is converted to gas equivalents at the rate of six
     Mcf  per  barrel,  representing  the  estimated  relative  energy
     content  of gas and oil, which rate is not necessarily indicative
     of the relationship of oil and gas prices.  The respective prices
     of  oil and  gas  are affected  by  market and  other factors  in
     addition to relative energy content.


     Proved Reserves and Net Present Value

     The following table sets forth the Program's estimated proved oil
and  gas reserves and net  present value therefrom  as of December 31,
1995.  The schedule of  quantities of proved oil and gas  reserves was
prepared  by Dyco  in  accordance with  the  rules prescribed  by  the
Securities and  Exchange Commission (the  "SEC").  As  used throughout
this  Annual  Report,  "proved  reserves" refers  to  those  estimated
quantities  of crude oil, natural  gas, and natural  gas liquids which
geological and engineering data demonstrate with  reasonable certainty
to be recoverable in  future years from known  oil and gas  reservoirs
under existing economic and operating conditions.


                                   7
<PAGE>
<PAGE>
     Net  present value  represents estimated  future gross  cash flow
from  the production and sale of proved reserves, net of estimated oil
and  gas  production costs  (including  production  taxes, ad  valorem
taxes, and operating expenses), and estimated future development costs
discounted at 10%  per annum.  Net  present value attributable to  the
Program's proved reserves was calculated on the basis of current costs
and  prices  at December 31,  1995.   Such  prices were  not escalated
except  in  certain circumstances  where  escalations  were fixed  and
readily   determinable   in   accordance   with   applicable  contract
provisions.   The prices used by  Dyco in calculating the  net present
value attributable to the Program's proved reserves do not necessarily
reflect market  prices  for  oil  and  gas  production  subsequent  to
December 31, 1995.   Furthermore, gas prices at December 31, 1995 were
higher than the price  used for determining the Program's  net present
value of proved reserves for the  year ended December 31, 1994.  There
can  be  no assurance  that  the prices  used in  calculating  the net
present value  of the Program's  proved reserves at  December 31, 1995
will actually be realized for such production.

     The process  of  estimating  oil  and gas  reserves  is  complex,
requiring  significant  subjective  decisions  in  the  evaluation  of
available  geological,   engineering,  and  economic   data  for  each
reservoir.   The data for  a given reservoir  may change substantially
over time as a  result of, among other things,  additional development
activity,  production  history,  and  viability  of  production  under
varying economic conditions; consequently,  it is reasonably  possible
that material revisions to existing reserve estimates may occur in the
near future.  Although every reasonable effort has been made to ensure
that the reserve estimates reported herein represent the most accurate
assessment  possible, the  significance  of  the subjective  decisions
required  and variances in available  data for various reservoirs make
these estimates generally less  precise than other estimates presented
in connection with financial statement disclosures.


                          Proved Reserves and
                           Net Present Value
                         From Proved Reserves

                        As of December 31, 1995


          Estimated proved reserves:
            Natural gas (Mcf)                2,216,455
            Oil and liquids (Bbls)               5,561

          Net present value
            (discounted at 10% per annum)   $2,337,792


                                   8
<PAGE>
<PAGE>
     No  estimates of the proved reserves of the Program comparable to
those included herein  have been  included in reports  to any  federal
agency other than  the SEC.   Additional information  relating to  the
Program's  proved reserves  is contained  in Note 4  to  the Program's
financial statements, included in Item 8 of this Annual Report. 


     Significant Properties 

     As of December 31, 1995, the Program's properties consisted of 23
gross (3.41 net) productive wells in which the Program owned a working
interest.  The Program owned a non-working interest in an additional 4
gross wells.  Affiliates of the Program operate 14 (52%)  of its total
wells.  As  of December 31, 1995, the  Program's net interests  in its
properties   resulted   in   estimated   total   proved   reserves  of
2,216,455 Mcf of natural gas and 5,561 barrels  of oil, with a present
value (discounted at 10% per annum) of estimated future  net cash flow
of  $2,337,792.   Substantially  all  of  the Program's  reserves  are
located  in the  Anadarko  Basin of  western  Oklahoma and  the  Texas
panhandle,  which is an established oil and  gas producing basin.  All
of the  Program's properties  are located onshore  in the  continental
United States.

     As of December 31, 1995, the Program's properties in the Anadarko
Basin  consisted of  22 gross  (3.08 net) wells  in which  the Program
owned a working interest.  The Program owned a non-working interest in
an additional 4  gross wells.   Affiliates of  the Program operate  13
(50%) of  its total wells in  the Anadarko Basin.   As of December 31,
1995, the Program's net  interest in such wells resulted  in estimated
total  proved reserves of  approximately 2,054,486 Mcf  of natural gas
and approximately 5,561  barrels of  crude oil, with  a present  value
(discounted at  10% per annum)  of estimated  future net cash  flow of
approximately $2,179,645.


     Title to Oil and Gas Properties

     Management believes  that the  Program has satisfactory  title to
its oil  and gas properties.  Record title to substantially all of the
Program's properties is held by Dyco as nominee.

     Title  to  the  Program's  properties  is  subject  to  customary
royalty,  overriding  royalty,  carried,  working,  and  other similar
interests and  contractual arrangements customary  in the oil  and gas
industry,  to  liens for  current  taxes not  yet  due,  and to  other
encumbrances.  Management believes that such burdens do not materially
detract  from the  value  of such  properties  or from  the  Program's
interest therein  or  materially  interfere  with  their  use  in  the
operation of the Program's business.  


                                   9
<PAGE>
<PAGE>
ITEM 3.   LEGAL PROCEEDINGS

     To  the  knowledge of  the management  of  Dyco and  the Program,
neither Dyco, the Program, nor the Program's properties are subject to
any litigation, the results  of which would have a material  effect on
the Program's or Dyco's financial condition or operations. 

ITEM 4.   SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS

     There were no matters submitted to a vote of the limited partners
during 1995.

                               PART II 

ITEM 5.   MARKET FOR  THE REGISTRANT'S LIMITED  PARTNERSHIP UNITS  AND
          RELATED LIMITED PARTNER MATTERS

     The Program does not  have an established trading market  for its
units  of  limited partnership  interest ("Units").   Pursuant  to the
terms of the Program's limited partnership agreement, Dyco, as General
Partner,  is obligated to annually  offer a repurchase  offer which is
based on the estimated future net revenues from the Program's reserves
and is calculated  pursuant to  the terms of  the limited  partnership
agreement.   Such repurchase offer is recalculated monthly in order to
reflect cash  distributions made  to  the limited  partners and  other
extraordinary events.  The following table sets forth, for the periods
indicated,  Dyco's repurchase  offer per  Unit and  the amount  of the
Program's  cash distributions  per  Unit for  the  same period.    For
purposes  of  this  Annual  Report,  a  Unit  represents   an  initial
subscription of $5,000 to a Program.

                           Repurchase        Cash
                              Price      Distributions
                           ----------    -------------

       1994:
         First Quarter       $241             $40
         Second Quarter       283              35
         Third Quarter        253              30
         Fourth Quarter       233              20

       1995:
         First Quarter       $233               -
         Second Quarter       264               -
         Third Quarter        234              30
         Fourth Quarter       234               -

       1996:
         First Quarter       $234             (1)

----------
(1)  To be declared in March 1996.

                                  10
<PAGE>
<PAGE>


     The Program  has 7,676 Units outstanding  and approximately 2,843
limited partners of record.


                               11
<PAGE>
<PAGE>
ITEM 6.   SELECTED FINANCIAL DATA
<TABLE>
<CAPTION>
                                    Selected Financial Data

     The following table presents selected financial data for the Program.  This data should be
read in  conjunction with  the financial statements  of the  Program, and the  respective notes
thereto,  included elsewhere  in this  Annual  Report.   See "Item 8. Financial  Statements and
Supplementary Data."  

                                                                   December 31,
                               ------------------------------------------------------------
                                  1995        1994        1993         1992        1991
                               ----------  ----------  ----------  ----------  ------------
<S>                            <C>         <C>         <C>         <C>          <C>  
Summary of Operations:
  Oil and gas sales            $  596,733  $1,102,809  $1,755,875  $1,548,661   $  931,805
  Total revenues                  605,334   1,108,840   1,762,579   1,598,151      994,898

  Lease operating
    expenses                      236,512     234,770     207,755     100,949      172,194
  Production taxes                 47,823      82,633     124,329     107,473       75,678
  General and administrative
    expenses                       92,351      85,280      89,492      87,427       65,005
  Depreciation, depletion,
    and amortization of oil
    and gas properties            116,583     295,422     382,135     311,561      304,541
  Valuation allowance for
    oil and gas properties           -           -           -           -       1,413,526
  Interest expense                   -           -           -           -           8,094

  Net income (loss)               112,065     410,735     958,868     990,741  ( 1,044,140)
    per Unit                           15          54         125         129  (       136)
  Cash distributions              230,280     959,500   1,420,060   1,036,260      844,360
    per Unit                           30         125         185         135          110

Summary Balance Sheet Data:
  Total assets                  1,141,415   1,155,672   1,621,406   1,997,942    2,147,111
  Partners' capital               860,979     979,194   1,527,959   1,989,151    2,034,670

</TABLE>

                                               12
<PAGE>
<PAGE>
ITEM 7.   MANAGEMENT'S  DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
          AND RESULTS OF OPERATIONS

     Results of Operations

                                General
                                -------

     The following  general discussion  should be read  in conjunction
with  the  analysis  of results  of  operations  provided  below.   In
management's view, it is not possible to predict accurately either the
short-term or  long-term prices for oil or  gas.  Specifically, due to
the  oversupply of  natural  gas  in  recent  years,  certain  of  the
Program's  gas producing  properties  have suffered,  and continue  to
suffer  during  portions  of  the year,  production  curtailments  and
seasonal reductions  in the  prices  paid by  purchasers.   Additional
curtailments and seasonal or  regional price reductions will adversely
affect the operations  and financial  condition of the  Program.   Gas
sales prices,  which have  generally declined significantly  since the
mid-1980s,  increased during the fourth quarter of 1995.  See "Item 1.
Business - Competition and Marketing."   Actual future prices received
by  the Program will likely be different  from (and may be lower than)
the prices in effect on December 31,  1995.  In many past years, year-
end prices have tended  to be higher, and in  some cases significantly
higher, than the yearly average price actually received by the Program
for  at   least  the  year  following  the  year-end  valuation  date.
Management is unable  to predict  whether future gas  prices will  (i)
stabilize,  (ii) increase,  or  (iii) decrease.    The amount  of  the
Program's  cash flow, however, is dependent on such future gas prices.



                Year Ended December 31, 1995 Compared 
                    to Year Ended December 31, 1994
                --------------------------------------

     Total oil and gas sales decreased 45.9% for the year ended Decem-
ber 31, 1995 as  compared to the year  ended December 31, 1994.   This
decrease was due to decreases in both the volumes and average price of
natural  gas sold and the volumes of  oil sold, partially offset by an
increase in the average price of oil sold.  Volumes of oil and natural
gas sold decreased by  708 barrels and 206,295 Mcf,  respectively, for
the  year  ended  December 31, 1995  as  compared  to  the year  ended
December 31, 1994.    The decrease  in  the volumes  of oil  sold  was
primarily due to  sporadic oil production on  three significant wells.
Volumes  of  natural   gas  sold  decreased   primarily  due  to   the
deterioration of  the producing  capabilities of the  Program's wells.
Average oil prices  increased to $17.43 per barrel for  the year ended
December 31,   1995  from  $15.53  per   barrel  for  the  year  ended
December 31,  1994.  Average natural gas prices decreased to $1.20 per
Mcf for  the year ended December 31,  1995 from $1.56 per  Mcf for the
year ended December 31, 1994.  

                                  13
<PAGE>
<PAGE>
     Oil  and  gas  production  expenses  (including  lease  operating
expenses and  production taxes) decreased  $33,068 for the  year ended
December 31, 1995  as compared  to the year  ended December 31,  1994.
This  decrease was primarily due  to lower production taxes associated
with  the decrease  in oil  and gas  sales discussed  above, partially
offset   by  workover   expenses  incurred   during  the   year  ended
December 31, 1995.    As a  percentage  of oil  and  gas sales,  these
expenses  increased to 47.6% for the year ended December 31, 1995 from
28.8%  for the year ended December 31, 1994.  This percentage increase
was primarily  a result  of the  significant decrease  in oil  and gas
sales during the year ended December 31, 1995.  

     Depreciation,   depletion,  and  amortization   of  oil  and  gas
properties decreased by $178,839 for  the year ended December 31, 1995
as compared  to the year ended  December 31, 1994.  This  decrease was
primarily a result of the decrease in oil and natural  gas sales and a
significant  increase  in  the  estimate of  the  Program's  remaining
natural gas  reserves during 1995.   As  a percentage of  oil and  gas
sales, this expense decreased to 19.5% for the year ended December 31,
1995 from 26.8% for the year ended December 31, 1994.  This percentage
decrease  was primarily  due  to  the  increase  in  the  estimate  of
remaining natural gas reserves discussed above.  

     General and  administrative expenses increased by  $7,071 for the
year  ended  December 31,   1995  as  compared   to  the  year   ended
December 31, 1994.   This dollar  increase resulted primarily  from an
increase in both  professional fees and printing  and postage expenses
during the year  ended December 31,  1995 as compared  to the  similar
period  in 1994.  As a  percentage of oil and  gas sales, this expense
increased to  15.5% for the year ended December 31, 1995 from 7.7% for
the year  ended  December 31,  1994.   This  percentage  increase  was
primarily  a result  of  the decrease  in oil  and  natural gas  sales
discussed above.  


                 Year Ended December 31, 1994 Compared
                    to Year Ended December 31, 1993
                 -------------------------------------

     Total  oil and  gas  sales decreased  37.2%  for the  year  ended
December 31, 1994  as compared  to the  year ended  December 31, 1993.
This decrease was due to decreases in the volumes and average price of
natural  gas sold  and a decrease  in the  average price  of oil sold,
partially offset  by an increase in  volumes of oil sold.   Volumes of
oil sold increased by 336 barrels for the year ended December 31, 1994
as  compared to  the year  ended December 31,  1993, while  volumes of
natural gas sold decreased 266,637 Mcf for the year ended December 31,
1994  as compared  to the  similar period  in 1993.   The  decrease in
volumes  of natural gas sold  was primarily a  result of deteriorating
natural production capabilities on a significant well during the year 

                                  14
<PAGE>
<PAGE>
ended December 31, 1994.  Average oil and natural gas prices decreased
to $15.53 per barrel and $1.56 per Mcf for the year ended December 31,
1994  from $16.90  per barrel  and $1.81  per Mcf  for the  year ended
December 31, 1993.

     Oil  and  gas  production  expenses  (including  lease  operating
expenses and production taxes) decreased slightly by 4.4% for the year
ended  December 31, 1994  as compared  to the year  ended December 31,
1993.   As a percentage of oil and gas sales, these expenses increased
to 28.8% for the year ended December 31, 1994 from 18.9%  for the year
ended December 31,  1993.  This  percentage increase  was primarily  a
result of the  decreases in the  volumes and average price  of natural
gas sold.

     Depreciation,  depletion,   and  amortization  of   oil  and  gas
properties decreased  by $86,713 for the year  ended December 31, 1994
as compared  to the year  ended December 31, 1993.   This decrease was
primarily a  result of the decrease in the volumes of natural gas sold
and  a significant increase in the estimate of the Program's remaining
natural gas  reserves during  1994.   As a percentage  of oil  and gas
sales, this expense increased to 26.8% for the year ended December 31,
1994 from 21.8% for the year ended December 31, 1993.  This percentage
increase was  primarily due to the decrease  in the volumes of natural
gas  sold, partially  offset  by  the  increase  in  the  estimate  of
remaining natural gas reserves discussed above.

     General and  administrative expenses decreased by  $4,212 for the
year  ended  December 31,   1994  as  compared   to  the  year   ended
December 31, 1993.   This dollar  decrease resulted  primarily from  a
decrease  in professional fees during the year ended December 31, 1994
as compared to the similar period in 1993.  As a percentage of oil and
gas sales, this expense increased slightly  to 7.7% for the year ended
December 31, 1994  from  5.1% for  the year  ended December 31,  1993.
This percentage increase  was primarily  a result of  the decrease  in
volumes and average price of natural gas sold.


     Liquidity and Capital Resources 

     Net proceeds from operations less necessary operating capital are
distributed to the limited partners  on a quarterly basis.   See "Item
5. Market for  the Registrant's Limited Partnership  Units and Related
Limited  Partner Matters."  The  net proceeds from  production are not
reinvested in productive assets,  except to the extent that  producing
wells  are  improved, or  where methods  are  employed to  permit more
efficient  recovery  of  reserves,  thereby resulting  in  a  positive
economic impact.    Assuming  production  levels for  the  year  ended
December 31,   1995,  the  Program's   proved  reserve  quantities  at
December 31, 1995 would have a life of approximately 4.6 years for gas
reserves and 8.0 years for oil reserves.


                                  15
<PAGE>
<PAGE>
     The  Program's  available  capital  from  the  limited  partners'
subscriptions  has been spent on  oil and gas  drilling activities and
there  should be no  further material capital  resource commitments in
the  future.    The  Program  has  no  debt  commitments.    Cash  for
operational  purposes  will  be  provided   by  current  oil  and  gas
production.

     There  can be  no assurance  as to  the  amount of  the Program's
future  cash  distributions.    The Program's  ability  to  make  cash
distributions depends primarily upon the level  of available cash flow
generated  by  the  Program's  operating  activities,  which  will  be
affected  (either positively or negatively) by many factors beyond the
control of the Program, including the price of and demand  for oil and
natural gas, and other market and economic conditions.  Even if prices
and   costs  remain  stable,   the  amount   of  cash   available  for
distributions will decline over time (as the volume of production from
producing  properties declines)  since  the Program  is not  replacing
production through acquisitions of producing  properties and drilling.



     Inflation and Changing Prices

     Prices obtained for oil and  gas production depend upon  numerous
factors,  including the  extent  of domestic  and foreign  production,
foreign imports of oil,  market demand, domestic and foreign  economic
conditions in general, and governmental regulations and tax laws.  The
general level  of inflation in  the economy  did not  have a  material
effect on the operations of the Program in 1995.   Oil and natural gas
prices  have fluctuated  during recent  years  and generally  have not
followed the same pattern as inflation.  See "Item 2. Properties - Oil
and Gas Production, Revenue, and Price History."


                                  16
<PAGE>
<PAGE>
ITEM 8.   FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

                   REPORT OF INDEPENDENT ACCOUNTANTS

TO THE PARTNERS

DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP

     We have audited the  financial statements of the Dyco Oil and Gas
Program 1983-1 Limited  Partnership (a Minnesota  limited partnership)
as listed in Item 14(a) of this Form 10-K.  These financial statements
are   the   responsibility  of   the   Program'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 dis-
closures  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
the  Dyco   Oil  and  Gas   Program  1983-1  Limited   Partnership  at
December 31, 1995 and 1994, and the results of its operations and cash
flows for each  of the  three years in  the period ended  December 31,
1995, in conformity with generally accepted accounting principles.  


                              COOPERS & LYBRAND L.L.P.

Tulsa, Oklahoma
February 6, 1996

                                  17
<PAGE>
<PAGE>
                       DYCO OIL AND GAS PROGRAM
                      1983-1 LIMITED PARTNERSHIP
                            Balance Sheets
                      December 31, 1995 and 1994

                                ASSETS
                                ------
                                              1995        1994
                                           ----------  ----------
CURRENT ASSETS:
  Cash and cash equivalents                $  173,345  $   59,992
  Accrued oil and gas sales, including
    $101,934 and $138,468 due from
    related parties                           119,412     158,161
                                            ---------   ---------
    Total current assets                   $  292,757  $  218,153

NET OIL AND GAS PROPERTIES, utilizing
  the full cost method                        782,694     885,812

DEFERRED CHARGE                                65,964      51,707
                                            ---------   ---------
                                           $1,141,415  $1,155,672
                                            =========   =========

                   LIABILITIES AND PARTNERS' CAPITAL
                   ---------------------------------

CURRENT LIABILITIES:
  Accounts payable                         $    8,531  $   39,425
  Gas imbalance payable                        90,223       9,893
                                            ---------   ---------
    Total current liabilities              $   98,754  $   49,318

ACCRUED LIABILITY                             181,682     127,160

PARTNERS' CAPITAL:
  General Partner, issued and
    outstanding, 76 Units                       8,610       9,792
  Limited Partners, issued and
    outstanding, 7,600 Units                  852,369     969,402
                                            ---------   ---------
    Total Partners' capital                $  860,979  $  979,194
                                            ---------   ---------

                                           $1,141,415  $1,155,672
                                            =========   =========


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

                                  18
<PAGE>
<PAGE>
                       DYCO OIL AND GAS PROGRAM
                      1983-1 LIMITED PARTNERSHIP
                       Statements of Operations
         For the Years Ended December 31, 1995, 1994, and 1993


                                  1995        1994        1993
                               ----------  ----------  ----------
REVENUES:
  Oil and gas sales including
    $584,600, $1,081,000,
    and $1,647,714 of sales 
    to related parties         $  596,733  $1,102,809  $1,755,875
  Interest                          8,601       6,031       6,704
                                ---------   ---------   ---------
                               $  605,334  $1,108,840  $1,762,579

COSTS AND EXPENSES:
  Lease operating              $  236,512  $  234,770  $  207,755
  Production taxes                 47,823      82,633     124,329
  Depreciation, depletion,
    and amortization of oil
    and gas properties            116,583     295,422     382,135
  General and administrative       92,351      85,280      89,492
                                ---------   ---------   ---------

                               $  493,269  $  698,105  $  803,711
                                ---------   ---------   ---------

NET INCOME                     $  112,065  $  410,735  $  958,868
                                =========   =========   =========

GENERAL PARTNER (1%) -
  NET INCOME                   $    1,121  $    4,107  $    9,589
                                =========   =========   =========

LIMITED PARTNERS (99%) -
  NET INCOME                   $  110,944  $  406,628  $  949,279
                                =========   =========   =========

NET INCOME per Unit            $       15  $       54  $      125
                                =========   =========   =========

UNITS OUTSTANDING                   7,676       7,676       7,676
                                =========   =========   =========


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

                                  19
<PAGE>
<PAGE>
                       DYCO OIL AND GAS PROGRAM
                      1983-1 LIMITED PARTNERSHIP
                    Statements of Partners' Capital
         For the Years Ended December 31, 1995, 1994, and 1993


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

Balances at Dec. 31, 1992    $19,892    $1,969,259    $1,989,151
  Cash distributions        ( 14,201)  ( 1,405,859)  ( 1,420,060)
  Net income                   9,589       949,279       958,868
                              ------     ---------     ---------

Balances at Dec. 31, 1993    $15,280    $1,512,679    $1,527,959
  Cash distributions        (  9,595)  (   949,905)  (   959,500)
  Net income                   4,107       406,628       410,735
                              ------     ---------     ---------

Balances at Dec. 31, 1994    $ 9,792    $  969,402    $  979,194
  Cash distributions        (  2,303)  (   227,977)  (   230,280)
  Net income                   1,121       110,944       112,065
                              ------     ---------     ---------

Balances at Dec. 31, 1995    $ 8,610    $  852,369    $  860,979
                              ======     =========     =========


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

                                  20
<PAGE>
<PAGE>
                       DYCO OIL AND GAS PROGRAM
                      1983-1 LIMITED PARTNERSHIP
                       Statements of Cash Flows
         For the Years Ended December 31, 1995, 1994, and 1993

                                      1995        1994          1993
                                   ----------  -----------  ------------
CASH FLOWS FROM OPERATING ACTIVITIES:
  Net income                        $112,065    $410,735     $  958,868
  Adjustments to reconcile net
    income to net cash provided
    by operating activities:
    Depreciation, depletion, and
      amortization of oil and gas
      properties                     116,583     295,422        382,135
    Decrease in accrued oil and 
      gas sales                       38,749     104,868         30,054
    Increase in deferred charge    (  14,257)  (  51,707)          -
    Increase (decrease) in
      accounts payable             (  30,894)  (  12,738)        43,372
    Increase in gas imbalance 
      payable                         80,330       4,753          5,140
    Increase in accrued liability     54,522      91,016         36,144
                                     -------     -------      ---------
  Net cash provided by operating
    activities                      $357,098    $842,349     $1,455,713
                                     -------     -------      ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
  Additions to oil and gas 
    properties                     ($ 14,456)  ($  9,955)   ($   14,043)
  Retirements of oil and gas
    properties                           991        -                28
                                     -------     -------      ---------
  Net cash used by investing
    activities                     ($ 13,465)  ($  9,955)   ($   14,015)
                                     -------     -------      ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
  Cash distributions               ($230,280)  ($959,500)   ($1,420,060)
                                     -------     -------      ---------
  Net cash used by financing
    activities                     ($230,280)  ($959,500)   ($1,420,060)
                                     -------     -------      ---------
NET INCREASE (DECREASE) IN CASH
  AND CASH EQUIVALENTS              $113,353   ($127,106)    $   21,638

CASH AND CASH EQUIVALENTS AT
  BEGINNING OF PERIOD                 59,992     187,098        165,460
                                     -------     -------      ---------
CASH AND CASH EQUIVALENTS AT 
  END OF PERIOD                     $173,345    $ 59,992     $  187,098
                                     =======     =======      =========

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

                                  21
<PAGE>
<PAGE>
          DYCO OIL AND GAS PROGRAM 1983-1 LIMITED PARTNERSHIP
                     Notes to Financial Statements
         For the Years Ended December 31, 1995, 1994, and 1993

1.   ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

     Organization and Nature of Operations

     The  Dyco Oil  and Gas  Program 1983-1  Limited Partnership  (the
     "Program"), a Minnesota limited partnership, commenced operations
     on  July 1, 1983.    Dyco Petroleum  Corporation ("Dyco")  is the
     General Partner  of  the  Program.    Affiliates  of  Dyco  owned
     2,759.26 (35.9%) of the Program's Units at December 31, 1995.

     The Program's sole business is the development  and production of
     oil  and  natural  gas  with  a  concentration  on  natural  gas.
     Substantially all of the Program's natural gas reserves are being
     sold  regionally in  the  "spot  market."    Due  to  the  highly
     competitive  nature of the spot market, prices on the spot market
     are subject  to wide seasonal and  regional pricing fluctuations.
     In addition, such  spot market sales are generally  short-term in
     nature  and are  dependent upon  the obtaining  of transportation
     services provided by pipelines.  


     Cash and Cash Equivalents

     The  Program  considers  all  highly liquid  investments  with  a
     maturity  of three  months  or less  when  purchased to  be  cash
     equivalents.  Cash  equivalents are not insured, which  cause the
     Program to be subject to risk.


     Credit Risk

     Accrued oil and gas sales which are due from a variety of oil and
     natural gas purchasers subject the Program  to a concentration of
     credit risk.  Some of these purchasers  are discussed in Note 3 -
     Major Customers.   


     Oil and Gas Properties 

     Oil  and gas  operations are  accounted for  using the  full cost
     method of  accounting.   All productive and  non-productive costs
     associated with the acquisition, exploration,  and development of
     oil  and gas  reserves  are capitalized.   Capitalized  costs are
     depleted on a  composite gross revenue method using  estimates of
     proved reserves.  The full cost amortization rates per equivalent
     Mcf of  gas produced  during the  years ended  December 31, 1995,
     1994,  and 1993 were $0.24,  $0.42, and $0.40,  respectively.  In
     the  event the unamortized cost  of oil and  gas properties being
     amortized  exceeds  the  full cost  ceiling  (as  defined  by the
     Securities  and Exchange  Commission)  the excess  is charged  to
     expense  in the  year  during  which  such  excess  occurs.    In
     addition, the  Securities and  Exchange Commission  rules provide
     that if prices decline subsequent to year end, any excess that 

                                  22
<PAGE>
<PAGE>
     results from these declines may also be charged to expense during
     the  current year.    Sales and  abandonments  of properties  are
     accounted for as adjustments of capitalized costs with no gain or
     loss  recognized, unless  such  adjustments  would  significantly
     alter the  relationship between capitalized costs  and proved oil
     and gas reserves.


     Deferred Charge  

     Deferred  Charge  represents costs  deferred for  lease operating
     expenses incurred  in connection with the Program's underproduced
     gas imbalance  position.  At December 31,  1995, cumulative total
     gas  sales volumes  for underproduced  wells were  less than  the
     Program's pro-rata share of total gas production from these wells
     by 166,576 Mcf, resulting in prepaid lease operating expenses  of
     $65,964.    At  December 31,  1994, cumulative  total  gas  sales
     volumes for underproduced wells were less than the Program's pro-
     rata  share of total gas  production from these  wells by 206,416
     Mcf, resulting in prepaid lease operating expenses of $51,707.  


     Accrued Liability  

     Accrued Liability represents charges accrued  for lease operating
     expenses incurred in connection  with the Program's  overproduced
     gas imbalance  position.  At December 31,  1995, cumulative total
     gas sales  volumes for overproduced wells  exceeded the Program's
     pro-rata share  of  total  gas  production from  these  wells  by
     458,794  Mcf, resulting  in accrued  lease operating  expenses of
     $181,682.    At December 31,  1994,  cumulative  total gas  sales
     volumes for overproduced  wells exceeded  the Program's  pro-rata
     share  of total gas  production from these  wells by 507,625 Mcf,
     resulting in accrued lease operating expenses of $127,160.  


     Oil and Gas Sales and Gas Imbalance Payable  

     The  Program's  oil  and  condensate production  is  sold,  title
     passed, and  revenue recognized  at or  near the Program's  wells
     under  short-term  purchase  contracts  at  prevailing prices  in
     accordance  with  arrangements which  are  customary  in the  oil
     industry.    Sales of  natural  gas applicable  to  the Program's
     interest in producing oil and gas leases are recorded as


                                  23
<PAGE>
<PAGE>
     income  when the gas is metered and title transferred pursuant to
     the  gas  sales  contracts  covering the  Program's  interest  in
     natural gas reserves.   During such times as the  Program's sales
     of gas  exceed its pro rata  ownership in a well,  such sales are
     recorded as income unless total sales from the well have exceeded
     the Program's  share of  estimated total gas  reserves underlying
     the  property  at  which  time  such  excess  is  recorded  as  a
     liability.    At  December 31,  1995, total  sales  exceeded  the
     Program's share of estimated total gas reserves on three wells by
     $90,233 (44,445 Mcf).  At December 31, 1994, total sales exceeded
     the Program's share of  estimated total gas reserves on  one well
     by  $9,893 (6,870  Mcf).   These  amounts  were recorded  as  gas
     imbalance payables in accordance with the sales method.  


     Use of Estimates in Financial Statements

     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.
     Further,  accrued oil and gas sales, the deferred charge, the gas
     imbalance  payable,  and  the   accrued  liability  all   involve
     estimates which  could materially differ from  the actual amounts
     ultimately realized  or incurred in  the near term.   Oil and gas
     reserves (see  Note 4)  also involve significant  estimates which
     could  materially  differ  from  the  actual  amounts  ultimately
     realized.   


     Income Taxes

     Income  or  loss for  income tax  purposes  is includable  in the
     income tax returns of the partners.   Accordingly, no recognition
     has  been given  to  income taxes  in the  accompanying financial
     statements.


2.   TRANSACTIONS WITH RELATED PARTIES 

     Under the terms of  the Program's partnership agreement, Dyco  is
     entitled to receive  a reimbursement for all  direct expenses and
     general  and administrative, geological, and engineering expenses
     it incurs  on behalf  of the  Program.   During  the years  ended
     December 31, 1995, 1994, and 1993, such expenses totaled $92,351,
     $85,280, and  $89,492, respectively,  of which  $71,280, $71,280,
     and $70,593, were paid to Dyco and its affiliates.

                                  24
<PAGE>
<PAGE>
     Affiliates  of  the  Program  operate certain  of  the  Program's
     properties.   Their  policy  is  to  bill  the  Program  for  all
     customary charges and  cost reimbursements associated  with these
     activities, together with any compressor  rentals, consulting, or
     other services provided.

     The Program sells  gas at  market prices to  Premier Gas  Company
     ("Premier") and Premier may then resell such gas to third parties
     at market prices.   Premier was an affiliate of the Program until
     December  6,  1995.   During 1995,  1994,  and 1993,  these sales
     totaled $584,600, $1,081,000,  and $1,647,714, respectively.   At
     December 31,  1995 and 1994,  accrued oil and  gas sales included
     $101,934 and $138,468, respectively, due from Premier.


3.   MAJOR CUSTOMERS

     The following purchaser individually  accounted for more than 10%
     of the combined oil and gas revenues (excluding the gas imbalance
     adjustment) of the Program for the years ended December 31, 1995,
     1994, and 1993:


             Purchaser       1995     1994     1993
             ---------      -----    -----    -----

             Premier        98.0%    98.0%    93.8%

     In the  event of interruption  of purchases  by this  significant
     customer or the  cessation or material change in  availability of
     open-access    transportation    by   the    Program's   pipeline
     transporters, the Program  may encounter difficulty in  marketing
     its  gas and in  maintaining historic sales  levels.  Alternative
     purchasers or transporters may not be readily available.  


4.   SUPPLEMENTAL OIL AND GAS INFORMATION

     The following supplemental information  regarding the oil and gas
     activities of the Program is presented pursuant to the disclosure
     requirements   promulgated  by   the   Securities  and   Exchange
     Commission.


                                  25
<PAGE>
<PAGE>
     Capitalized Costs

     The Program's  capitalized  costs and  accumulated  depreciation,
     depletion, amortization, and valuation allowance were as follows:


                                        December 31,
                                ----------------------------
                                    1995           1994
                                -------------  -------------

     Proved properties           $35,411,185    $35,397,720

     Unproved properties, not
       subject to depreciation,
       depletion, and amorti-
       zation                           -              -
                                  ----------     ----------
                                 $35,411,185    $35,397,720

     Less accumulated depre-
       ciation, depletion,
       amortization, and
       valuation allowance      ( 34,628,491)  ( 34,511,908)
                                  ----------     ----------

     Net oil and gas properties  $   782,694    $   885,812
                                  ==========     ==========


     Costs Incurred

     Costs incurred by the Program in connection with  its oil and gas
     property  acquisition,  exploration,  and development  activities
     were as follows:


                                          December 31,
                                   -------------------------
                                    1995     1994     1993
                                   -------  -------  -------

     Acquisition of properties     $  -     $  -     $  -
     Exploration costs                -        -        -
     Development costs              14,456    9,955   14,043
                                    ------   ------   ------

     Total costs incurred          $14,456  $ 9,955  $14,043
                                    ======   ======   ======

                                  26
<PAGE>
<PAGE>
     Quantities of Proved Oil and Gas Reserves - Unaudited
<TABLE>
<CAPTION>
     Set forth below is a summary of the changes in the net quantities of the Program's  proved
     crude  oil and natural gas reserves for the years ended December 31, 1995, 1994, and 1993.
     Proved reserves were estimated by petroleum engineers employed by affiliates of Dyco.  All
     of the Program's reserves are located in the United States.


                                   1995                    1994                    1993
                           --------------------    --------------------    --------------------
                             Oil        Gas          Oil        Gas          Oil        Gas
                           (Bbls)      (Mcf)       (Bbls)      (Mcf)       (Bbls)      (Mcf)
                           -------  -----------    -------  -----------    -------  -----------
<S>                        <C>       <C>            <C>      <C>           <C>      <C>
Proved reserves,
  beginning of year         5,888    2,248,380      6,455    2,686,871      9,270    3,893,779

Revisions of previous
  estimates                   369      453,249        837      252,978     (1,747)  (  248,802)

Sales of reserves            -            -          -            -          -            -

Extensions and
  discoveries                -            -          -            -          -            -

Production                 (  696)  (  485,174)    (1,404)  (  691,469)    (1,068)  (  958,106)
                            -----    ---------      -----    ---------      -----    ---------

Proved reserves,
  end of year               5,561    2,216,455      5,888    2,248,380      6,455    2,686,871
                            =====    =========      =====    =========      =====    =========

Proved developed reserves:
  Beginning of year         5,888    2,239,789      6,455    2,677,810      9,270    3,883,641
                            -----    ---------      -----    ---------      -----    ---------
  End of year               4,418    1,911,490      5,888    2,239,789      6,455    2,677,810
                            =====    =========      =====    =========      =====    =========


                                               27
<PAGE>
<PAGE>
     The  process  of  estimating oil  and  gas  reserves is  complex,
     requiring significant  subjective decisions in the  evaluation of
     available geological,  engineering, and  economic  data for  each
     reservoir.    The   data  for  a   given  reservoir  may   change
     substantially  over time  as  a result  of,  among other  things,
     additional   development   activity,   production  history,   and
     viability of  production under varying economic  conditions; con-
     sequently, it  is reasonably possible that  material revisions to
     existing  reserve  estimates  may   occur  in  the  near  future.
     Although every reasonable effort has been made to ensure that the
     reserve  estimates  reported herein  represent the  most accurate
     assessment possible, the significance of the subjective decisions
     required and  variances in available data  for various reservoirs
     make these estimates generally  less precise than other estimates
     presented in connection with financial statement disclosures.


ITEM 9.   CHANGES IN AND DISAGREEMENTS WITH  ACCOUNTANTS ON ACCOUNTING
          AND FINANCIAL DISCLOSURE

     None.

                               PART III


ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT

     The  Program is  a limited  partnership and  has no  directors or
executive  officers.   The  following  individuals  are directors  and
executive  officers of Dyco, General Partner.  The business address of
such  directors  and executive  officers  is Two  West  Second Street,
Tulsa, Oklahoma  74103.

           NAME        AGE         POSITION WITH DYCO
     ----------------  ---  --------------------------------
     C. Philip Tholen   47  Chief Executive Officer, Presi-
                              dent, and Chairman of the
                              Board of Directors

     Dennis R. Neill    43  Senior Vice President and
                              Director

     Jack A. Canon      46  Senior Vice President -
                              General Counsel and Director

     Patrick M. Hall    37  Senior Vice President - 
                              Controller

     Annabel M. Jones   42  Secretary

     Judy F. Hughes     49  Treasurer


                                  28
<PAGE>
<PAGE>
The  directors will  hold  office until  the  next annual  meeting  of
shareholders of Dyco and until their successors have been duly elected
and qualified.   All executive officers serve at the discretion of the
Board of Directors.

     C. Philip Tholen  joined  the Samson  Companies in  1977 and  has
served  as President,  Chief Executive Officer,  and Director  of Dyco
since June 18, 1991.  Prior to joining the Samson Companies, he was an
audit  manager for Arthur Andersen & Co. in Tulsa where he specialized
in oil and natural gas industry audits and contract audits.   He holds
a  Bachelor of  Science degree  in accounting  from the  University of
Tulsa  and is  a  Certified Public  Accountant.   Mr. Tholen  is  also
Executive Vice  President,  Chief Financial  Officer,  Treasurer,  and
Director of Samson  Investment Company; President and  Chairman of the
Board of Directors of Samson  Natural Gas Company, Geodyne  Resources,
Inc. and its subsidiaries, and Samson Resources Company; President  of
two  Divisions  of  Samson  Natural Gas  Company,  Samson  Exploration
Company and Samson Production Services Company; Senior Vice President,
Treasurer,  and   Director  of  Samson  Properties  Incorporated;  and
Director  of   Circle L   Drilling  Company   and  Samson   Industrial
Corporation.

     Dennis R. Neill joined the Samson Companies in 1981 and was named
Senior Vice President and Director of Dyco on June 18, 1991.  Prior to
joining the Samson Companies, he was associated with a Tulsa law firm,
Conner and Winters, where his principal practice was in the securities
area.  He received a Bachelor of Arts degree in political science from
Oklahoma  State  University  and a  Juris  Doctorate  degree from  the
University  of Texas.  Mr. Neill also serves as Senior Vice President,
Chief   Operating  Officer,   and   Director   of  Samson   Properties
Incorporated;  Senior Vice  President of Samson  Hydrocarbons Company;
Senior  Vice President and Director of Geodyne Resources, Inc. and its
subsidiaries;  and President and Chairman of the Board of Directors of
Samson Securities Company.

     Jack A.  Canon joined the Samson Companies in 1983 and has served
as  a Vice President and Director of Dyco  since June 18, 1991.  Prior
to joining the  Samson Companies, he  served as  a staff attorney  for
Terra Resources,  Inc. and was  associated with the Tulsa  law firm of
Dyer, Powers, Marsh, Turner and Armstrong.  He received a Bachelor  of
Science degree in accounting from Quincy College and a Juris Doctorate
degree  from  the  University of  Tulsa.    Mr. Canon  also serves  as
Secretary of Samson Investment Company; Director of Samson Natural Gas
Company, Samson  Properties Incorporated,  Circle L  Drilling Company,
and Samson Securities Company; Senior Vice President - General Counsel
of Samson Production  Services Company, a  Division of Samson  Natural
Gas Company,  and Geodyne Resources,  Inc. and  its subsidiaries;  and
Vice President - General Counsel of Samson Industrial Corporation.


                                  29
<PAGE>
<PAGE>
     Patrick M. Hall joined the Samson Companies in 1983 and was named
a  Vice President of  Dyco on  June 18,  1991.   Prior to  joining the
Samson Companies he was  a senior accountant with Peat  Marwick Main &
Co. in Tulsa.   He holds  a Bachelor of  Science degree in  accounting
from Oklahoma State  University and is a  Certified Public Accountant.
Mr. Hall is also a Director of Samson Natural Gas  Company and Geodyne
Resources,  Inc.  and  its   subsidiaries;  Senior  Vice  President  -
Controller and Director of  Samson Properties Incorporated; and Senior
Vice President -  Controller of Samson Production  Services Company, a
Division of Samson Natural Gas Company.

     Annabel  M. Jones  joined the  Samson Companies  in 1982  and was
named Secretary of Dyco on June 18, 1991.  Prior to joining the Samson
Companies  she served  as associate  general counsel  of the  Oklahoma
Securities  Commission.    She  holds Bachelor  of  Arts  in political
science and  Juris Doctorate degrees from the  University of Oklahoma.
Ms. Jones serves as Assistant  General Counsel - Corporate Affairs for
Samson Production Services  Company, a Division of  Samson Natural Gas
Company,  and is  also  Secretary of  Samson Properties  Incorporated,
Samson  Natural   Gas  Company,   Geodyne  Resources,  Inc.   and  its
subsidiaries,  and  Samson  Industrial   Corporation;  Vice-President,
Secretary, and  Director of  Samson Securities Company;  and Assistant
Secretary of Samson Investment Company.

     Judy F. Hughes  joined the Samson Companies in 1978 and was named
Treasurer  of Dyco  on June  18, 1991.   Prior  to joining  the Samson
Companies,  she  performed treasury  functions  with  Reading &  Bates
Corporation.  She attended the University of Tulsa and  also serves as
Treasurer  of Samson Natural Gas Company,  Geodyne Resources, Inc. and
its  subsidiaries,   and  Samson  Securities  Company   and  Assistant
Treasurer   of  Samson   Investment  Company  and   Samson  Industrial
Corporation.


ITEM 11.  EXECUTIVE COMPENSATION


     The  Program is  a  limited partnership  and,  therefore, has  no
officers or  directors.   The following table  summarizes the  amounts
paid by the Program as compensation and reimbursements to Dyco and its
affiliates for the three years ended December 31, 1995:


                                  30
<PAGE>
<PAGE>
         Compensation/Reimbursement to Dyco and its affiliates
                  Three Years Ended December 31, 1995

Type of Compensation/Reimbursement(1)            Expense
-------------------------------------   -------------------------
                                         1995     1994     1993
                                        -------  -------  -------
Compensation:
  Operations                            $   (2)  $   (2)  $   (2)
  Gas Marketing(3)                      $   (3)  $   (3)  $   (3)

Reimbursements:
  General and Administrative,
    Geological, and Engineering
    Expenses and Direct Expenses(4)     $71,280  $71,280  $70,593

----------

(1)  The authority for all  of such compensation and  reimbursement is
     the  limited partnership agreement of the  Program.  With respect
     to  the  Operations activities  noted  in  the table,  management
     believes that such  compensation is  equal to or  less than  that
     charged by unaffiliated persons in  the same geographic areas and
     under the same conditions.
(2)  Affiliates of the  Program serve as operator of a majority of the
     Program's wells.  Dyco,  as General Partner, contracts with  such
     affiliates for services as  operator of the wells.   As operator,
     such  affiliates  are  compensated   at  rates  provided  in  the
     operating agreements in effect and charged to all parties to such
     agreement.   The dollar amount  of such compensation  paid by the
     Program  to such affiliates is  impossible to quantify  as of the
     date of this Annual Report. 
(3)  Premier, an  affiliate  of the  Program until  December 6,  1995,
     purchased a portion  of the  Program's gas at  market prices  and
     resold  such gas at market prices directly to end-users and local
     distribution companies.   For the years  ended December 31, 1995,
     1994,  and  1993,  the  Program sold  $584,600,  $1,081,000,  and
     $1,647,714, respectively, of gas to Premier. 
(4)  The Program reimburses Dyco and its affiliates for reasonable and
     necessary general and administrative, geological, and engineering
     expenses and  direct expenses  incurred in connection  with their
     management  and  operation  of   the  Program.    The  directors,
     officers,  and employees  of Dyco and  its affiliates  receive no
     direct remuneration  from the Program  for their services  to the
     Program.  See "Salary Reimbursement  Table" below.  The allocable
     general  and administrative, geological, and engineering expenses
     are  apportioned  on a  reasonable  basis  between the  Program's
     business and all other oil and natural gas activities of Dyco and
     its  affiliates, including  Dyco's  management  and operation  of
     affiliated oil and  gas limited partnerships.   The allocation to
     the Program of these costs is made by Dyco as General Partner.


                                  31
<PAGE>
<PAGE>
     As  noted  in  the  Compensation/Reimbursement  Table  above, the
directors,  officers,  and  employees  of Dyco  and  their  affiliates
receive  no direct remuneration  from the Program  for their services.
However, to the extent such services represent direct involvement with
the Program, as opposed to  general corporate functions, such persons'
salaries  are  allocated  to and  reimbursed  by  the  Program.   Such
allocation to  the Program's  general and  administrative, geological,
and engineering expenses of  the salaries of directors, officers,  and
employees  of Dyco  and its  affiliates is  based on  internal records
maintained  by  Dyco  and  its  affiliates,  and  represents  investor
relations, legal, accounting,  data processing, management, and  other
functions  directly attributable  to  the Program's  operations.   The
following  table  indicates  the  approximate amount  of  general  and
administrative expense  reimbursement attributable to the  salaries of
the  directors, officers, and employees of Dyco and its affiliates for
the three years ended December 31, 1995:


                                  32
<PAGE>
<PAGE>

</TABLE>
<TABLE>
<CAPTION>
                                      Salary Reimbursement

                              Three Years Ended December 31, 1995

                                                         Long Term Compensation
                                                     -------------------------------
                            Annual Compensation             Awards           Payouts
                         -------------------------   ---------------------   -------
                                                                   Securi-
                                            Other                   ties                 All
     Name                                   Annual   Restricted    Under-               Other
      and                                  Compen-     Stock       lying      LTIP     Compen-
   Principal             Salary     Bonus  sation     Award(s)    Options/   Payouts   sation
   Position       Year     ($)       ($)     ($)        ($)        SARs(#)     ($)       ($)
---------------   ----   -------   ------- -------   ----------   --------   -------   -------
<S>               <C>    <C>       <C>     <C>       <C>          <C>        <C>       <C>
C. Philip 
Tholen,
President,
Chief Executive
Officer<F1>       1993     -         -       -         -            -          -         -
                  1994     -         -       -         -            -          -         -
                  1995     -         -       -         -            -          -         -

All Executive
Officers, 
Directors,
and Employees
as a group<F2>    1993   $37,414     -       -         -            -          -         -
                  1994   $38,848     -       -         -            -          -         -
                  1995   $38,919     -       -         -            -          -         -

----------
<FN>
<F1> The general  and administrative expenses  paid by the  Program and attributable  to salary
     reimbursements do not include any salary or other compensation attributable to Mr. Tholen.
<F2> No officer  or director  of  Dyco or  its affiliates  provides full-time  services to  the
     Program and no  individual's salary or other  compensation reimbursement from the  Program
     equals or exceeds $100,000 per annum.
</FN>
</TABLE>

                                               33
<PAGE>
<PAGE>
     In  addition  to  the  compensation/reimbursements  noted  above,
during  the three years ended December 31,  1995, the Samson Companies
were in the  business of  supplying field and  drilling equipment  and
services to affiliated and unaffiliated parties in the industry.  Such
companies  may have provided equipment and services for wells in which
the  Program has  an  interest.   These  equipment and  services  were
provided  at prices  or rates  equal  to or  less than  those normally
charged in  the same  or comparable  geographic  area by  unaffiliated
persons or companies dealing  at arm's length.  The operators of these
wells  bill the  Program for a  portion of  such costs  based upon the
Program's interest in the well.


ITEM 12.  SECURITY   OWNERSHIP  OF   CERTAIN  BENEFICIAL   OWNERS  AND
          MANAGEMENT

     The  following table  provides information  as to  the beneficial
ownership  of  the Program's  Units as  of  December 31, 1995  by each
beneficial owner of more than  5% of the issued and  outstanding Units
and  by the directors, officers, and affiliates  of Dyco.  The address
of  each of  such persons  is Samson  Plaza, Two  West Second  Street,
Tulsa, Oklahoma 74103.  


                                            Number of Units
                                             Beneficially
                                            Owned (Percent
            Beneficial Owner                of Outstanding)
     -------------------------------       -----------------

     Samson Properties Incorporated        2,759.26  (35.9%)

     All directors, officers, and 
       affiliates of Dyco as a group
       and Dyco (8 persons)                2,759.26  (35.9%)


     To the best  knowledge of  the Program  and Dyco,  there were  no
officers,  directors,  or 5%  owners  who  were  delinquent filers  of
reports  required under section 16  of the Securities  Exchange Act of
1934.

                                  34
<PAGE>
<PAGE>
ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

     Dyco  and certain  of  its  affiliates  engage  in  oil  and  gas
activities  independently of the Program  which result in conflicts of
interest  that  cannot  be  totally eliminated.    The  allocation  of
acquisition  and   drilling  opportunities  and  the   nature  of  the
compensation  arrangements between  the Program  and Dyco  also create
potential  conflicts of  interest.   Dyco  and  its affiliates  own  a
significant  amount  of the  Program's  Units  and therefore  have  an
identity of interest with  other limited partners with respect  to the
operations of the Program. 

     In  order  to attempt  to  assure limited  liability  for limited
partners as well  as an orderly conduct of business, management of the
Program is exercised solely by Dyco.  The partnership agreement of the
Program grants Dyco broad discretionary authority with respect to  the
Program's  participation  in drilling  prospects  and expenditure  and
control of funds, including borrowings.   These provisions are similar
to  those contained  in  prospectuses and  partnership agreements  for
other public oil and gas partnerships.  Broad discretion as to general
management  of  the  Program  involves circumstances  where  Dyco  has
conflicts of interest and  where it must allocate costs  and expenses,
or opportunities, among the Program and other competing interests. 

     Dyco  does not  devote all  of its  time, efforts,  and personnel
exclusively  to the Program.   Furthermore, the Program  does not have
any  employees,  but instead  relies on  the  personnel of  the Samson
Companies.    The  Program thus  competes  with  the Samson  Companies
(including other  currently sponsored oil  and gas  programs) for  the
time and resources  of such  personnel.  The  Samson Companies  devote
such  time  and personnel  to the  management  of the  Program  as are
indicated  by the  circumstances  and as  are  consistent with  Dyco's
fiduciary duties. 

     Affiliates  of  the  Program   are  solely  responsible  for  the
negotiation,  administration, and  enforcement  of oil  and gas  sales
agreements covering the Program's leasehold interests.  Until December
6,  1995,  Dyco had  delegated  the  negotiation, administration,  and
enforcement  of its  oil  and gas  sales  agreements to  Premier.   In
addition to  providing such administrative services, Premier purchased
and resold gas directly to end-users and local distribution companies.
Because  affiliates of the Program who provide services to the Program
have  fiduciary or  other  duties  to  other  members  of  the  Samson
Companies, contract amendments and negotiating positions taken by them
in  their  effort  to  enforce   contracts  with  purchasers  may  not
necessarily  represent the positions that the Program would take if it
were to  administer its own  contracts without involvement  with other
members  of the  Samson  Companies.   On  the other  hand,  management
believes  that  the  Program's negotiating  strength  and  contractual
positions have been  enhanced by  virtue of its  affiliation with  the
Samson Companies. 

                                  35
<PAGE>
<PAGE>
     For  a description  of  certain other  relationships and  related
transactions, see "Item 11. Executive Compensation."


                                PART IV


ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM
          8-K

          (a)  Financial  Statements  and  Schedules.   The  following
     financial  statements  and  schedules   for  the  Program  as  of
     December 31,  1995 and 1994 and  for the years ended December 31,
     1995, 1994, and 1993 are filed as part of this report.

          (1)  Financial Statements:
               Report of Independent Accountants
               Balance Sheets
               Statements of Operations
               Statements of Partners' Capital
               Statements of Cash Flows
               Notes to Financial Statements

          (2)  Financial Statement Schedules:

               None

          All  other schedules  have been  omitted since  the required
     information is  presented in the  Financial Statements or  is not
     applicable.

          (b)  Reports on Form 8-K for the fourth quarter of 1995:

               None.

          (c)  Exhibits:

               4.1  Program Agreement dated March 1, 1983 for Dyco Oil
                    and  Gas  Program  1983-1  by   and  between  Dyco
                    Petroleum Corporation and the participants.  Filed
                    as  Exhibit 4.1 to Annual  Report on Form 10-K for
                    the year ended December 31,  1991 on April 6, 1992
                    and is hereby incorporated by reference.

               4.2  Drilling  Agreement dated  March 1, 1983  for Dyco
                    Drilling Program 1983-1  by and  between Dyco  Oil
                    and   Gas   Program    1983-1,   Dyco    Petroleum
                    Corporation,   and  Jaye  F.   Dyer.     Filed  as
                    Exhibit 4.2 to Annual Report  on Form 10-K for the
                    year ended December 31, 1991 on  April 6, 1992 and
                    is hereby incorporated by reference.

                                  36
<PAGE>
<PAGE>
               4.3  Amendment to  Program Agreement for  Dyco Oil  and
                    Gas Program 1983-1 dated  February 9, 1989.  Filed
                    as Exhibit 4.3 to  Annual Report on  Form 10-K for
                    the year ended December 31,  1991 on April 6, 1992
                    and is hereby incorporated by reference.

               4.4  Certificate  of  Limited Partnership,  as amended,
                    for  Dyco  Oil  and  Gas  Program  1983-1  Limited
                    Partnership.    Filed  as  Exhibit 4.4  to  Annual
                    Report   on   Form 10-K   for   the   year   ended
                    December 31, 1991  on April 6, 1992  and is hereby
                    incorporated by reference.

               27.1 Financial   Data   Schedule   containing   summary
                    financial information extracted from the  Dyco Oil
                    and  Gas  Program  1983-1   Limited  Partnership's
                    financial statements  as of December 31,  1995 and
                    for the year ended December 31, 1995.  

               All other Exhibits are omitted as inapplicable. 


                                  37
<PAGE>
<PAGE>
                              SIGNATURES

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

                              DYCO OIL AND GAS PROGRAM 1983-1 
                              LIMITED PARTNERSHIP

                              By:  DYCO PETROLEUM CORPORATION
                                   General Partner
                                   February 16, 1996

                              By:  /s/C. Philip Tholen
                                   ------------------------------
                                   C. Philip Tholen
                                   Chief Executive Officer 
                                   and President

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 registrant and in the capacities on the dates indicated.

By:  /s/C. Philip Tholen    Chief Executive        Feb. 16, 1996
     -------------------    Officer, President,
        C. Philip Tholen    and Chairman of the
                            Board (Principal
                            Executive Officer)

     /s/Dennis R. Neill     Senior Vice            Feb. 16, 1996 
     -------------------    President and
        Dennis R. Neill     Director

     /s/Jack A. Canon       Senior Vice            Feb. 16, 1996
     -------------------    President - 
        Jack A. Canon       General Counsel
                            and Director

     /s/Patrick M. Hall     Senior Vice            Feb. 16, 1996
     -------------------    President - 
        Patrick M. Hall     Controller 
                            (Principal 
                            Accounting Officer)

     /s/Annabel M. Jones    Secretary              Feb. 16, 1996
     -------------------
        Annabel M. Jones

     /s/Judy F. Hughes      Treasurer              Feb. 16, 1996
     -------------------
        Judy F. Hughes


                                  38
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<PAGE>
                           INDEX TO EXHIBITS


Exhibit
Number    Description
-------   -----------

4.1       Program Agreement dated March 1,  1983 for Dyco Oil and  Gas
          Program 1983-1 by and between Dyco Petroleum Corporation and
          the participants.  Filed as Exhibit 4.1  to Annual Report on
          Form 10-K  for the year ended December 31,  1991 on April 6,
          1992 and is hereby incorporated by reference.

4.2       Drilling  Agreement dated  March 1,  1983 for  Dyco Drilling
          Program 1983-1 by and between Dyco Oil and Gas Program 1983-
          1, Dyco Petroleum Corporation,  and Jaye F. Dyer.   Filed as
          Exhibit 4.2 to Annual Report on Form 10-K for the year ended
          December 31,  1991  on     April  6,  1992   and  is  hereby
          incorporated by reference.

4.3       Amendment  to Program Agreement for Dyco Oil and Gas Program
          1983-1  dated February  9, 1989.   Filed  as  Exhibit 4.3 to
          Annual Report  on Form 10-K for the  year ended December 31,
          1991  on  April  6,  1992  and  is  hereby  incorporated  by
          reference.

4.4       Certificate of Limited Partnership, as amended, for Dyco Oil
          and  Gas  Program  1983-1  Limited Partnership.    Filed  as
          Exhibit 4.4 to Annual Report on Form 10-K for the year ended
          December 31,   1991  on   April  6,   1992  and   is  hereby
          incorporated by reference.  

27.1      Financial   Data   Schedule  containing   summary  financial
          information  extracted from  the  Dyco Oil  and Gas  Program
          1983-1  Limited  Partnership's  financial statements  as  of
          December 31, 1995 and for the year ended December 31, 1995.  


                                  39
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