FORM 10-K405

                 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, 1999

Commission File Number 0-8881

                   DYCO OIL AND GAS PROGRAM 1978-1
                       (A LIMITED PARTNERSHIP)
       (Exact name of registrant as specified in its charter)

           Minnesota                   41-1343930
(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-K405 or any amendment to this Form 10-K405.  [X]

      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.




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<PAGE>






                            FORM 10-K405

                   DYCO 1978-1 OIL AND GAS PROGRAM
                  (A Minnesota limited partnership)

                          TABLE OF CONTENTS


PART I.........................................................................3

      ITEM 1.   BUSINESS.......................................................3
      ITEM 2.   PROPERTIES.....................................................7
      ITEM 3.   LEGAL PROCEEDINGS.............................................11
      ITEM 4.   SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS...........12

PART II.......................................................................12

      ITEM 5.   MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS AND
                RELATED LIMITED PARTNER MATTERS...............................12
      ITEM 6.   SELECTED FINANCIAL DATA.......................................13
      ITEM 7.   MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
                CONDITION AND RESULTS OF OPERATIONS...........................15
      ITEM 7A.  QUANTITIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET
                RISK..........................................................19
      ITEM 8.   FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA...................20
      ITEM 9.   CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
                ACCOUNTING AND FINANCIAL DISCLOSURE...........................34

PART III......................................................................34

      ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT............34
      ITEM 11.  EXECUTIVE COMPENSATION........................................35
      ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
                MANAGEMENT....................................................39
      ITEM 13.  CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS................39

PART IV.......................................................................41

      ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON
                FORM 8-K......................................................41

SIGNATURES....................................................................43




                                      -2-
<PAGE>





                                     PART I


ITEM 1.   BUSINESS

      General

      The Dyco Oil and Gas Program 1978-1 Limited Partnership (the "Program") is
a Minnesota  limited  partnership  engaged in the production of oil and gas. The
Program  commenced  operations  on April 1,  1978  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.
Samson  Resources  Company,  an  affiliate  of Dyco,  currently  owns  more than
one-half of the  Program's  Units of limited  partnership  interest,  making the
Program a 50% subsidiary of Samson Resources  Company.  See "Item 2. Properties"
for a description of the Program's reserves and properties.

      The  limited   partnership   agreement   for  the  Program  (the  "Program
Agreement")  provides  that limited  partners are  allocated  99% of all Program
costs and revenues and 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  currently  serves as General  Partner  of 31  limited  partnerships,
including  the  Program.  Dyco and Samson  Resources  Company  are  wholly-owned
subsidiaries of Samson Investment  Company.  Samson  Investment  Company and its
various corporate  subsidiaries,  including Dyco,  (collectively,  "Samson") are
primarily  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, 1999,  Samson owned interests in  approximately  14,000 oil and gas
wells  located in 17 states of the United  States and the  countries  of Canada,
Venezuela, and Russia. At December 31, 1999, Samson operated approximately 3,400
oil and gas wells located in 15 states of the United States,  as well as 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 Samson. As of March 1,
2000,  Samson employed  approximately  920 persons.  No employees are covered by
collective bargaining agreements, and management believes that Samson provides a
sound employee relations  environment.  For information  regarding the executive
officers  of Dyco,  see  "Item  10.  Directors  and  Executive  Officers  of the
Registrant."



                                      -3-
<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) 283-1791.


      Funding

      Although the Program  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
gas with a  concentration  on 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 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 gas may be subject to both federal and state laws
and  regulations.  The provisions of these laws and  regulations are complex and
affect all who  produce,  resell,  transport,  or purchase  gas,  including  the
Program.  Although  virtually all of the Program's gas production is not subject
to  price  regulation,   other  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.



                                      -4-
<PAGE>



      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,  may increase the cost of the Program's  operations or may affect
the  Program's  ability  to  timely  complete  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 El Paso Energy Marketing Company ("El Paso") accounted
for approximately 92.1% of the Program's oil and gas sales during the year ended
December 31, 1999. 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.


      Competition and Marketing

      The  domestic  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), United Nations export embargoes, the supply and price
of foreign  imports of oil and gas, the level of consumer  product demand (which
can be 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



                                      -5-
<PAGE>



of these  factors on future oil and gas industry  trends  cannot be  accurately
predicted or anticipated.

      The most important variable affecting the Program's revenues is the prices
received for the sale of oil and gas.  Predicting future prices is not possible.
Concerning past trends,  average yearly wellhead gas prices in the United States
have been volatile for many years.  Over the past ten years such average  prices
have  generally  been in the  $1.40 to  $2.40  per Mcf  range.  Gas  prices  are
currently in the upper end of this range.

      Substantially  all of the  Program's  gas  reserves  are being sold on the
"spot  market."  Prices on the spot  market  are  subject to wide  seasonal  and
regional pricing  fluctuations due to the highly  competitive nature of the spot
market. In addition,  such spot market sales are generally  short-term in nature
and are dependent  upon the  obtaining of  transportation  services  provided by
pipelines.  Spot prices for the Program's gas increased from approximately $1.93
per Mcf at December  31,  1998 to  approximately  $2.24 per Mcf at December  31,
1999.  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.

      For the past ten years,  average  oil prices  have  generally  been in the
$16.00 to $24.00 per barrel  range,  but have been  extremely  volatile over the
past two  years.  Due to  global  consumption  and  supply  trends  as well as a
slowdown in Asian energy demand,  oil prices in late 1997 and early 1998 reached
historically low levels,  dropping to as low as approximately  $9.00 per barrel.
However,  production  curtailment  agreements among major oil producing  nations
have  caused  recent  oil  prices  to climb to over  $30.00  per  barrel in some
markets.  It is not known  whether  this  trend  will  continue.  Prices for the
Program's oil increased from approximately $9.50 per barrel at December 31, 1998
to approximately $22.75 per barrel at December 31, 1999.

      Future  prices  for both oil and gas will  likely  be  different  from the
prices in effect on December 31, 1999.  Management is unable to predict  whether
future oil and 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



                                      -6-
<PAGE>



material  adverse  effect on the Program's  financial  condition 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, 1999.

                         Well Statistics(1)

                       As of December 31, 1999

           Gross productive wells(2):
                Oil                              1
                Gas                             11
                                                --
                     Total                      12

           Net productive wells(3):
                Oil                            .09
                Gas                            .39
                                               ---
                     Total                     .48

----------

(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 on Form 10-K405  ("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.  For example,  a 15%
      working 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, 1999.




                                      -7-
<PAGE>



      Oil and Gas Production, Revenue, and Price History

      The following table sets forth certain historical  information  concerning
the oil  (including  condensates)  and  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,
                                  --------------------------------
                                    1999       1998         1997
                                  --------   --------     --------
Production:
      Oil (Bbls)(1)                    263        382          405
      Gas (Mcf)(2)                  52,504     74,479      168,303

Oil and gas sales:
      Oil                         $  4,012   $  4,173     $  7,016
      Gas                          106,205    143,087      322,637
                                   -------    -------      -------

        Total                     $110,217   $147,260     $329,653
                                   =======    =======      =======

Total direct operating
   expenses(3)                    $ 28,897   $ 50,799     $ 94,591
                                   =======    =======      =======

Direct operating expenses
   as a percentage of oil
   and gas sales                     26.2%      34.5%        28.7%

Average sales price:
   Per barrel of oil                $15.25     $10.92       $17.32
   Per Mcf of gas                     2.02       1.92         1.92

Direct operating expenses per
   equivalent Mcf of gas(4)         $  .53     $  .66         $.55
----------

(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 gas.
(3)   Includes lease operating expenses and production taxes.
(4)   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



                                      -8-
<PAGE>



      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, 1999.  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").
Certain reserve  information was reviewed by Ryder Scott Company,  L.P.  ("Ryder
Scott"),  an independent  petroleum  engineering  firm. As used  throughout this
Annual Report,  "proved reserves" refers to those estimated  quantities of crude
oil, gas, and 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.

      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, 1999. 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, 1999.  There can be no assurance that the
prices  used in  calculating  the net  present  value  of the  Program's  proved
reserves at December 31, 1999 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 these  reserve
estimates 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.



                                      -9-
<PAGE>



                               Proved Reserves and
                                Net Present Value
                              From Proved Reserves

                           As of December 31, 1999 (1)

           Estimated proved reserves:
             Gas (Mcf)                                458,894
             Oil and liquids (Bbls)                     1,160

           Net present value
             (discounted at 10% per annum)           $412,437

-----------------

(1)   Includes certain gas balancing adjustments which cause the gas volumes and
      net present value to differ from the reserve reports  prepared by Dyco and
      reviewed by Ryder Scott.


      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 5 to the Program's financial statements, included in Item 8 of
this Annual Report.


      Significant Properties

      As of December 31, 1999,  the Program's  properties  consisted of 12 gross
(.48 net) productive wells. The Program also owned a non-working  interest in an
additional  14 wells.  Affiliates  of the Program  operate 11 (42%) of its total
wells.  All of the Program's  properties are located  onshore in the continental
United States.  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.

      As of December 31, 1999,  the Program's  properties in the Anadarko  Basin
consisted  of 11 gross (.39 net)  wells.  The Program  also owned a  non-working
interest in an  additional  13 wells in the Anadarko  Basin.  Affiliates  of the
Program  operate 9 (38%) of its total Anadarko  Basin wells.  As of December 31,
1999, the Program had estimated  total proved  reserves in the Anadarko Basin of
approximately  408,746  Mcf of gas and  approximately  715 barrels of crude oil,
with a present value  (discounted at 10% per annum) of estimated future net cash
flow of approximately $385,264.



                                      -10-
<PAGE>



      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.


ITEM 3.  LEGAL PROCEEDINGS

      On February 13, 1998,  Walter K. Spurlin  L.L.C.  filed a lawsuit  against
Dyco alleging that Dyco amended or terminated certain gas purchase contracts and
fraudulently  concealed the  settlement of these  contracts.  (Walter K. Spurlin
L.L.C., et al. vs. Dyco Petroleum Corporation,  CJ-98-3, District Court of Roger
Mills County,  Oklahoma.) The Plaintiff  filed the petition as a class action on
behalf of all individuals who leased Oklahoma  mineral leases to Dyco which were
subject  to certain  gas  purchase  contracts.  The  Plaintiff,  a lessor of the
Spurlin No. 1-23 well,  alleges that Dyco's actions  resulted in a breach of the
express and implied  obligations of the leases and reckless  indifference and/or
actual fraud on behalf of Dyco.  The  Plaintiff  has not specified the amount of
alleged  damages.  Dyco filed its answer in the matter on April 1, 1998 in which
it  denied  all  of  the  Plaintiff's  allegations  and  asserted  a  number  of
affirmative  defenses,  including  failure  to state a claim and  running of the
statute of  limitations.  Dyco's  affirmative  defenses  also  alleged  that the
Plaintiff's  claims were contrary to the Oklahoma  Supreme  Court's  decision in
Roye Realty and Developing,  Inc. v. Watson, 949 P.2d 1208 (Okla. 1996) and that
Dyco acted as a prudent operator and in accordance with the lease terms. A class
certification order was entered by the district court on February 25, 2000. Dyco
intends to pursue an  interlocutory  appeal of this  order.  The  Program had an
approximate  8.7%  working  interest  in the  Spurlin  No.  1-23 well during the
periods applicable to this lawsuit.

      Except for the  foregoing,  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.



                                      -11-
<PAGE>




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

      There  were  no  matters  submitted  to a vote  of the  Program's  limited
partners during 1999.


                                    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
Agreement, Dyco, as General Partner, is obligated to annually issue 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 Program Agreement.  Such
repurchase offer is recalculated  monthly in order to reflect cash distributions
made to the limited partners and 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 the Program.


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

      1998:
        First Quarter             $126                 $70
        Second Quarter              56                   -
        Third Quarter              120                  25
        Fourth Quarter              95                   -

      1999:
        First Quarter             $ 95                 $ -
        Second Quarter              95                   -
        Third Quarter              160                  20
Fourth Quarter                     140                   -

      2000:
        First Quarter             $140                 $ -


      As of  March  1,  2000,  the  Program  has  2,400  Units  outstanding  and
approximately 700 Limited Partners of record.



                                      -12-
<PAGE>




ITEM 6.    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."



                                      -13-
<PAGE>



<TABLE>
<CAPTION>



                                                        December 31,

                                    --------------------------------------------------------
                                      1999        1998        1997       1996         1995
                                    --------    --------    --------   --------     --------
<S>                                 <C>         <C>         <C>        <C>          <C>
Summary of Operations:
   Oil and gas sales                $110,217    $147,260    $329,653   $222,560     $188,215
   Total revenues                    111,165     149,733     331,988    224,511      190,843

   Lease operating expenses           21,137      39,941      70,618     46,425       49,891
   Production taxes                    7,760      10,858      23,973     16,290       13,220
   General and administrative
      expenses                        31,268      31,524      33,807     33,079       32,626
   Depreciation, depletion,
      and amortization of
      oil and gas properties          14,073      18,706      44,478     21,753       33,373
   Impairment provision                 -           -           -          -          13,949

   Net income                         36,927      48,704     159,112    106,964       47,784
      per Unit                         15.23       20.09       65.64      44.13        19.71
   Cash distributions                 48,480     230,280     133,320    109,080       96,960
      per Unit                            20          95          55         45           40

Summary Balance Sheet Data:
   Total assets                      155,839     165,851     357,596    314,601      323,611
   Partners' capital                 121,737     133,290     314,866    289,074      291,190

</TABLE>




                                      -14-
<PAGE>



ITEM 7.  MANAGEMENT'S  DISCUSSION  AND ANALYSIS OF  FINANCIAL  CONDITION
         AND RESULTS OF OPERATIONS

      Use of Forward-Looking Statements and Estimates

      This Annual Report contains certain forward-looking  statements. The words
"anticipate,"  "believe,"  "expect,"  "plan," "intend,"  "estimate,"  "project,"
"could," "may," and similar expressions are intended to identify forward-looking
statements.  Such statements reflect  management's current views with respect to
future  events and  financial  performance.  This Annual  Report  also  includes
certain information which is, or is based upon, estimates and assumptions.  Such
estimates and assumptions  are  management's  efforts to accurately  reflect the
condition and operation of the Program.

      Use of  forward-looking  statements and estimates and assumptions  involve
risks and uncertainties which include, but are not limited to, the volatility of
oil and gas prices, the uncertainty of reserve  information,  the operating risk
associated with oil and gas properties  (including the risk of personal  injury,
death, property damage, damage to the well or producing reservoir, environmental
contamination,  and other  operating  risks),  the  prospect of changing tax and
regulatory laws, the availability and capacity of processing and  transportation
facilities,  the  general  economic  climate,  the  supply  and price of foreign
imports of oil and gas, the level of consumer product demand,  and the price and
availability  of  alternative  fuels.  Should  one or more  of  these  risks  or
uncertainties  occur  or  should  estimates  or  underlying   assumptions  prove
incorrect,  actual  conditions or results may vary materially and adversely from
those stated, anticipated, believed, estimated, or otherwise indicated.


      General Discussion

      The following  general  discussion  should be read in conjunction with the
analysis of results of operations  provided below.  The most important  variable
affecting the Program's  revenues is the prices received for the sale of oil and
gas. Predicting future prices is not possible.  Concerning past trends,  average
yearly  wellhead  gas prices in the United  States have been  volatile  for many
years.  Over the past ten years such average  prices have  generally been in the
$1.40 to $2.40 per Mcf range.  Gas prices are currently in the upper end of this
range.

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



                                      -15-
<PAGE>



approximately  $1.93 per Mcf at December 31, 1998 to approximately $2.24 per Mcf
at  December  31,  1999.  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.

      For the past ten years,  average  oil prices  have  generally  been in the
$16.00 to $24.00 per barrel  range,  but have been  extremely  volatile over the
past two  years.  Due to  global  consumption  and  supply  trends  as well as a
slowdown in Asian energy demand,  oil prices in late 1997 and early 1998 reached
historically low levels,  dropping to as low as approximately  $9.00 per barrel.
However,  production  curtailment  agreements among major oil producing  nations
have  caused  recent  oil  prices  to climb to over  $30.00  per  barrel in some
markets.  It is not known  whether  this  trend  will  continue.  Prices for the
Program's oil increased from approximately $9.50 per barrel at December 31, 1998
to approximately $22.75 per barrel at December 31, 1999.

      Future  prices  for both oil and gas will  likely  be  different  from the
prices in effect on December 31, 1999.  Management is unable to predict  whether
future oil and gas prices will (i) stabilize, (ii) increase, or (iii) decrease.


      Results of Operations

                      Year Ended December 31, 1999 Compared
                         to Year Ended December 31, 1998
                      -------------------------------------

      Total oil and gas sales  decreased  $37,043 (25.2%) in 1999 as compared to
1998.  Of this  decrease,  approximately  $42,000  was  related to a decrease in
volumes of gas sold.  This  decrease  was  partially  offset by an  increase  of
approximately  $5,000  related to an increase in the average  price of gas sold.
Volumes of oil and gas sold decreased 119 barrels and 21,975 Mcf,  respectively,
in 1999 as compared to 1998.  The decrease in volumes of gas sold was  primarily
due to (i) a positive prior period volume adjustment made by the operator on one
well during 1998 and (ii) the Program receiving a reduced percentage of sales on
three wells during 1999 due to the Program's overproduced gas balancing position
in those wells. These decreases were partially offset by a negative prior period
volume adjustment made by the purchaser on another well during 1998. Average oil
and gas prices  increased to $15.25 per barrel and $2.02 per Mcf,  respectively,
in 1999 from $10.92 per barrel and $1.92 per Mcf, respectively, in 1998.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $21,902 (43.1%) in 1999 as compared to 1998. This
decrease  was  primarily  due to (i) a  decrease  in  lease  operating  expenses
associated with the decreases in volumes of oil and gas sold and (ii) workover




                                      -16-
<PAGE>




expenses  incurred on one well  during 1998 in order to improve the  recovery of
reserves.  As a percentage  of oil and gas sales,  these  expenses  decreased to
26.2% in 1999 from 34.5% in 1998. This percentage  decrease was primarily due to
the dollar decrease in oil and gas production expenses.

Depreciation,  depletion,  and amortization of oil and gas properties  decreased
$4,633  (24.8%) in 1999 as compared to 1998.  This decrease was primarily due to
the  decreases in volumes of oil and gas sold.  As a  percentage  of oil and gas
sales, this expense increased to 12.8% in 1999 from 12.7% in 1998.

      General and administrative  expenses remained  relatively constant in 1999
as  compared  to 1998.  As a  percentage  of oil and gas sales,  these  expenses
increased  to 28.4% in 1999 from 21.4% in 1998.  This  percentage  increase  was
primarily due to the decrease in oil and gas sales.



                      Year Ended December 31, 1998 Compared
                         to Year Ended December 31, 1997
                      -------------------------------------

      Total oil and gas sales decreased  $182,393 (55.3%) in 1998 as compared to
1997.  Of this  decrease,  approximately  $180,000  was related to a decrease in
volumes of gas sold. Volumes of oil and gas sold decreased 23 barrels and 93,824
Mcf,  respectively,  in 1998 as compared to 1997. The decrease in volumes of gas
sold resulted primarily from (i) a positive gas balancing adjustment made by the
operator on one well in 1997,  (ii) a positive  prior period  volume  adjustment
made by the  purchaser on another well during 1997,  and (iii) a negative  prior
period  volume  adjustment  made by the  purchaser  on a third well during 1998.
These  decreases  were  partially  offset  by a  positive  prior  period  volume
adjustment made by the operator on a fourth well during 1998. Average oil prices
decreased  to $10.92 per barrel in 1998 from $17.32 per barrel in 1997.  Average
gas prices remained constant at $1.92 per Mcf during 1998 and 1997.

      Oil and gas production  expenses  (including lease operating  expenses and
production  taxes)  decreased  $43,792 (46.3%) in 1998 as compared to 1997. This
decrease  resulted  primarily  from  decreases in (i) lease  operating  expenses
associated with the decreases in volumes of oil and gas sold and (ii) production
taxes  associated  with the decrease in oil and gas sales.  These decreases were
partially offset by workover  expenses incurred on one well during 1998 in order
to improve the recovery of reserves. As a percentage of oil and gas sales, these
expenses increased to 34.5% in 1998 from 28.7% in 1997. This percentage increase
was primarily due to the prior period  volume  adjustments  during 1998 and 1997
discussed above and the workover expenses incurred during 1998.




                                      -17-
<PAGE>




      Depreciation,  depletion,  and  amortization  of oil  and  gas  properties
decreased  $25,772 (57.9%) in 1998 as compared to 1997.  This decrease  resulted
primarily  from the  decrease  in  volumes  of oil and gas  sold  and an  upward
revision in the  estimate of remaining  gas reserves at December 31, 1998.  As a
percentage  of oil and gas sales,  this expense  decreased to 12.7% in 1998 from
13.5% in 1997.

      General and  administrative  expenses  decreased  $2,283 (6.8%) in 1998 as
compared to 1997. As a percentage of oil and gas sales, these expenses increased
to 21.4% in 1998 from 10.3% in 1997. This percentage  increase was primarily due
to the decrease in oil and gas sales.

      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 1999 production  levels for future years,
the  Program's  proved  reserve  quantities  at  December  31, 1999 would have a
remaining life of approximately 8.7 years for gas reserves and 4.4 years for oil
reserves.  However,  since the Program's  reserve estimates are based on oil and
gas prices at December 31, 1999, it is possible  that a significant  decrease in
oil and gas prices from  December 31, 1999 levels will reduce such  reserves and
their corresponding life-span.

      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.  Occasional expenditures by
the Program for well completions or workovers,  however, may reduce or eliminate
cash available for a particular  quarterly cash  distribution.  During 1999, the
Program  invested  $24,413 for the purchase of additional  gas reserves  (20,414
Mcf) in the Pankey Unit No. 1 well,  the Walter No. 1-24 well, and the Music No.
3-24 well in which the Program  owns  working  interests  of 6.77%,  7.41%,  and
1.70%,  respectively.  These  reserves  were  purchased  in order to assist  the
Program in reducing its gas imbalance  liabilities  on these wells.  The Program
has no debt  commitments.  Cash for  operational  purposes  has  generally  been
provided by current oil and gas  production.  Management  believes that cash for
ordinary  operational purposes in the future 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



                                      -18-
<PAGE>



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 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 1999.
Oil and 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."


      Year 2000 Computer Issues

      The year  2000  issue  refers  to the  inability  of  computer  and  other
information  technology  systems to properly process date and time  information,
stemming from the earlier  programming  practice of using two digits rather than
four to represent the year in a date.  To the knowledge of the General  Partner,
the Program has not experienced  any material  effects from the year 2000 issue.
Costs  incurred by the Program in order to ensure year 2000  compatibility  were
not material to the Program.


ITEM 7A.   QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET
           RISK.

      The Program does not hold any market risk sensitive instruments.





                                      -19-
<PAGE>




ITEM 8.   FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA




                  REPORT OF INDEPENDENT ACCOUNTANTS



TO THE PARTNERS

DYCO OIL AND GAS PROGRAM 1978-1 LIMITED PARTNERSHIP

      In our opinion, the accompanying balance sheets and the related statements
of operations,  changes in partners'  capital and cash flows present fairly,  in
all material  respects,  the financial  position of the Dyco Oil and Gas Program
1978-1 Limited  Partnership,  a Minnesota limited  partnership,  at December 31,
1999 and 1998,  and the results of its operations and its cash flows for each of
the three years in the period  ended  December  31,  1999,  in  conformity  with
accounting  principles  generally accepted in the United States. 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 of these financial  statements in accordance
with auditing standards  generally accepted in the United States,  which require
that we plan and perform the audit to obtain reasonable  assurance about whether
the financial  statements are free of material  misstatement.  An audit includes
examining,  on a test basis,  evidence supporting the amounts and disclosures in
the  financial   statements,   assessing  the  accounting  principles  used  and
significant  estimates made by management,  and evaluating the overall financial
statement  presentation.  We believe that our audits provide a reasonable  basis
for the opinion expressed above.









                               PricewaterhouseCoopers LLP



Tulsa, Oklahoma
March 11, 2000





                                      -20-
<PAGE>



                      DYCO OIL AND GAS PROGRAM
                     1978-1 LIMITED PARTNERSHIP
                           Balance Sheets
                     December 31, 1999 and 1998

                               ASSETS
                               ------
                                              1999         1998
                                            --------     --------
CURRENT ASSETS:
   Cash and cash equivalents                $  2,459     $ 24,203
   Accrued oil and gas sales                  20,310       18,937
                                             -------      -------
      Total current assets                  $ 22,769     $ 43,140

NET OIL AND GAS PROPERTIES, utilizing
   the full cost method                      121,369      105,692

DEFERRED CHARGE                               11,701       17,019
                                             -------      -------
                                            $155,839     $165,851
                                             =======      =======

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

CURRENT LIABILITIES:
   Accounts payable                         $  1,518     $  1,199
   Payable to General
     Partner (Note 1)                          5,000         -
                                             -------      -------
      Total current liabilities             $  6,518     $  1,199

ACCRUED LIABILITY                           $ 27,584     $ 31,362

CONTINGENCY (Note 4)

PARTNERS' CAPITAL:
   General Partner, 24 general
      partner units                         $  1,217     $  1,333
   Limited Partners, issued and
      outstanding, 2,400 Units               120,520      131,957
                                             -------      -------
      Total Partners' capital               $121,737     $133,290
                                             -------      -------
                                            $155,839     $165,851
                                             =======      =======





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



                                      -21-
<PAGE>



                            DYCO OIL AND GAS PROGRAM
                           1978-1 LIMITED PARTNERSHIP
                           Statements of Operations
             For the Years Ended December 31, 1999, 1998, and 1997


                                              1999        1998       1997
                                            --------    --------   --------
REVENUES:
   Oil and gas sales                        $110,217    $147,260   $329,653
   Interest                                      948       2,473      2,335
                                             -------     -------    -------
                                            $111,165    $149,733   $331,988

COSTS AND EXPENSES:
   Lease operating                          $ 21,137    $ 39,941   $ 70,618
   Production taxes                            7,760      10,858     23,973
   Depreciation, depletion, and
      amortization of oil and gas
      properties                              14,073      18,706     44,478
   General and administrative                 31,268      31,524     33,807
                                             -------     -------    -------

                                            $ 74,238    $101,029   $172,876
                                             -------     -------    -------

NET INCOME                                  $ 36,927    $ 48,704   $159,112
                                             =======     =======    =======

GENERAL PARTNER (1%) - NET INCOME           $    369    $    487   $  1,591
                                             =======     =======    =======

LIMITED PARTNERS (99%) - NET INCOME         $ 36,558    $ 48,217   $157,521
                                             =======     =======    =======

NET INCOME per Unit                         $  15.23    $  20.09   $  65.64
                                             =======     =======    =======

UNITS OUTSTANDING                              2,424       2,424      2,424
                                             =======     =======    =======








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




                                      -22-
<PAGE>




                            DYCO OIL AND GAS PROGRAM
                           1978-1 LIMITED PARTNERSHIP
                   Statements of Changes in Partners' Capital
             For the Years Ended December 31, 1999, 1998, and 1997


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

Balances at Dec. 31, 1996         $2,891     $286,183     $289,074
   Cash distributions            ( 1,333)   ( 131,987)   ( 133,320)
   Net income                      1,591      157,521      159,112
                                   -----      -------      -------

Balances at Dec. 31, 1997         $3,149     $311,717     $314,866
   Cash distributions            ( 2,303)   ( 227,977)   ( 230,280)
   Net income                        487       48,217       48,704
                                   -----      -------      -------

Balances at Dec. 31, 1998         $1,333     $131,957     $133,290
   Cash distributions            (   485)   (  47,995)   (  48,480)
   Net income                        369       36,558       36,927
                                   -----      -------      -------

Balances at Dec. 31, 1999         $1,217     $120,520     $121,737
                                   =====      =======      =======



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




                                      -23-
<PAGE>




                            DYCO OIL AND GAS PROGRAM
                           1978-1 LIMITED PARTNERSHIP
                           Statements of Cash Flows
             For the Years Ended December 31, 1999, 1998, and 1997


                                            1999        1998         1997
                                          --------    ---------    ---------
CASH FLOWS FROM OPERATING ACTIVITIES:
   Net income                              $36,927     $ 48,704     $159,112
   Adjustments to reconcile net
      income to net cash provided
      by operating activities:
      Depreciation, depletion, and
        amortization of oil
        and gas properties                  14,073       18,706       44,478
      (Increase) decrease in accrued
        oil and gas sales                 (  1,373)     119,746    (  91,842)
      (Increase) decrease in deferred
        charge                               5,318    (   4,683)      28,411
      Increase (decrease) in
        accounts payable                       319    (  18,174)      16,237
      Increase in payable
        to General Partner                   5,000         -            -
      Increase (decrease) in
        gas imbalance payable                 -       (     690)         690
      Increase (decrease) in
        accrued liability                 (  3,778)       8,695          276
                                            ------      -------      -------
   Net cash provided by
      operating activities                 $56,486     $172,304     $157,362
                                            ------      -------      -------

CASH FLOWS FROM INVESTING ACTIVITIES:
   Proceeds from the sale of
      oil and gas properties               $ 1,363     $  4,007     $     94
   Additions to oil and gas
      properties                          ( 31,113)   (     291)        -
                                            ------      -------      -------
   Net cash provided (used) by
      investing activities                ($29,750)    $  3,716     $     94
                                            ------      -------      -------

CASH FLOWS FROM FINANCING ACTIVITIES:
   Cash distributions                     ($48,480)   ($230,280)   ($133,320)
                                            ------      -------      -------
   Net cash used by financing
      activities                          ($48,480)   ($230,280)   ($133,320)
                                            ------      -------      -------



                                      -24-
<PAGE>




NET INCREASE (DECREASE) IN CASH
   AND CASH EQUIVALENTS                   ($21,744)   ($ 54,260)    $ 24,136

CASH AND CASH EQUIVALENTS AT
   BEGINNING OF PERIOD                      24,203       78,463       54,327
                                            ------      -------      -------
CASH AND CASH EQUIVALENTS AT
  END OF PERIOD                            $ 2,459     $ 24,203     $ 78,463
                                            ======      =======      =======







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



                                      -25-
<PAGE>



         DYCO OIL AND GAS PROGRAM 1978-1 LIMITED PARTNERSHIP
                    Notes to Financial Statements
        For the Years Ended December 31, 1999, 1998, and 1997


1.    ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

      Organization and Nature of Operations

           The  Dyco  Oil  and  Gas  Program  1978-1  Limited  Partnership  (the
      "Program"), a Minnesota limited partnership, commenced operations on April
      1, 1978. Dyco Petroleum Corporation ("Dyco") is the General Partner of the
      Program.  Affiliates of Dyco owned 1,205 (50.2%) of the Program's Units at
      December 31, 1999.

           The Program's sole business is the  development and production of oil
      and gas with a concentration  on gas.  Substantially  all of the Program's
      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.  The prices  received for the Program's oil and gas are subject
      to influences such as global consumption and supply trends.


      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 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 gross  revenue  method
      using estimates of proved reserves. The full




                                      -26-
<PAGE>




      cost  amortization  rates per  equivalent  Mcf of gas produced  during the
      years ended  December  31, 1999,  1998,  and 1997 were $0.26,  $0.24,  and
      $0.26, respectively. The Program's calculation of depreciation, depletion,
      and amortization  includes estimated future expenditures to be incurred in
      developing  proved  reserves and estimated  dismantlement  and abandonment
      costs, net of estimated  salvage values. 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 ("SEC")) the excess
      is charged to expense in the year during which such excess  occurs.  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

           The Deferred  Charge at December 31, 1999 and 1998  represents  costs
      deferred for lease  operating  expenses  incurred in  connection  with the
      Program's  underproduced  gas  imbalance  positions.   The  rate  used  in
      calculating  the deferred  charge is the average of the annual  production
      costs per Mcf. At December 31, 1999,  cumulative  total gas sales  volumes
      for  underproduced  wells were less than the Program's  pro-rata  share of
      total gas  production  on these wells by 32,182 Mcf,  resulting in prepaid
      lease  operating  expenses of $11,701.  At December 31,  1998,  cumulative
      total  gas  sales  volumes  for  underproduced  wells  were  less than the
      Program's  pro-rata share of total gas production on these wells by 49,245
      Mcf, resulting in prepaid lease operating expenses of $17,019.


      Payable to General Partner

           The Payable to General  Partner at December  31, 1999  represents  an
      operating  advance  from the  General  Partner.  Such amount was repaid in
      January 2000.


      Accrued Liability

           The  Accrued  Liability  at  December  31,  1999 and 1998  represents
      charges accrued for lease operating  expenses  incurred in connection with
      the  Program's  overproduced  gas  imbalance  positions.  The rate used in
      calculating the accrued  liability is the average of the annual production
      costs per Mcf. At December 31, 1999,  cumulative  total gas sales  volumes
      for overproduced  wells exceeded the Program's pro-rata share of total gas
      production  on these  wells by 75,863  Mcf,  resulting  in  accrued  lease
      operating expenses of



                                      -27-
<PAGE>



      $27,584.  At December 31,  1998,  cumulative  total gas sales  volumes for
      overproduced  wells  exceeded the  Program's  pro-rata  share of total gas
      production  on these  wells by 90,746  Mcf,  resulting  in  accrued  lease
      operating expenses of $31,362.


      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 gas  applicable to the
      Program's interest in producing oil and gas leases are recorded as revenue
      when the gas is metered  and title  transferred  pursuant to the gas sales
      contracts  covering the Program's  interest in 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 revenue 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. The rates per Mcf used to calculate this liability are based on
      the  average  gas  prices  received  for  the  volumes  at  the  time  the
      overproduction  occurred.  No such  liability was recorded at December 31,
      1999 or December 31, 1998.


      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,  the deferred charge, the accrued liability,  the gas
      imbalance payable, and the litigation contingency (see Note 4) all involve
      estimates which could materially differ from the actual amounts ultimately
      realized in the near term.  Oil and gas reserves (see Note 5) 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.  During 1999
      Samson



                                      -28-
<PAGE>



      Resources  Company's ownership of Units first exceeded 50%. As required by
      IRS regulations,  the Program's tax year has been changed to coincide with
      Samson's tax year of July 1 to June 30.


2.    TRANSACTIONS WITH RELATED PARTIES

           The Program  obtained an operating  advance from the General  Partner
      during the fourth  quarter of 1999 due to the  purchase of reserves on one
      well. Such amount was repaid in January 2000.

           Under the terms of the Program 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, 1999,  1998,  and 1997,  such expenses
      totaled $31,268, $31,524, and $33,807,  respectively, of which $24,876 was
      paid each year to Dyco and its affiliates.

           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.  Such
      charges are  comparable to third party charges in the area where the wells
      are located and are the same as charged to other working  interest  owners
      in the wells.


3.    MAJOR CUSTOMERS

           The following purchaser individually accounted for 10% or more of the
      combined oil and gas sales of the Program for the years ended December 31,
      1999, 1998, and 1997:

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

           El Paso Energy
             Marketing Company     92.1%    96.3%   87.3%

           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.




                                      -29-
<PAGE>




4.    CONTINGENCY

           On February 13, 1998,  a royalty  owner filed a lawsuit  against Dyco
      alleging  that Dyco amended or terminated  certain gas purchase  contracts
      and fraudulently concealed the settlement of these contracts.  The lawsuit
      involves  the Spurlin No.  1-23 Well.  Dyco has filed an Answer  asserting
      various  affirmative  defenses,  and  intends to  vigorously  defend  this
      lawsuit. A class  certification order was entered by the district court on
      February 25, 2000. Dyco intends to pursue an interlocutory  appeal of this
      order.  As of the date of these financial  statements,  the Program is not
      able to determine the ultimate  outcome of this lawsuit or the  assessment
      of any damages that may result.


5.    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 SEC.


      Capitalized Costs

           The  Program's   capitalized  costs  and  accumulated   depreciation,
      depletion,  amortization, and valuation allowance at December 31, 1999 and
      1998 were as follows:


                                           December 31,
                                   ----------------------------
                                       1999            1998
                                   -------------   -------------

      Proved properties             $14,966,100     $14,936,350

      Less accumulated depre-
        ciation, depletion,
        amortization, and
        valuation allowance        ( 14,844,731)   ( 14,830,658)
                                     ----------      ----------

      Net oil and gas properties    $   121,369     $   105,692
                                     ==========      ==========



                                      -30-
<PAGE>




      Costs Incurred

           The Program incurred no oil and gas property exploration costs during
      1999, 1998, and 1997. Costs incurred by the Program in connection with its
      oil and gas property  acquisition  (purchase of reserves) and  development
      activities during 1999, 1998, and 1997 were as follows:


                                           December 31,
                                    --------------------------
                                     1999       1998      1997
                                    -------    ------    ------

           Acquisition costs        $24,413      $ -      $ -
           Development costs          6,700       291       -
                                     ======       ===      ===




                                      -31-
<PAGE>




      Quantities of Proved Oil and Gas Reserves - Unaudited

           Set forth below is a summary of the changes in the net  quantities of
      the  Program's  proved  crude oil and gas  reserves  for the  years  ended
      December 31, 1999,  1998,  and 1997.  Proved  reserves  were  estimated by
      petroleum engineers employed by affiliates of the Program. Certain reserve
      information  was reviewed by Ryder Scott  Company,  L.P.,  an  independent
      petroleum  engineering firm. All of the Program's  reserves are located in
      the  United  States.  The  following   information  includes  certain  gas
      balancing  adjustments  which  cause the gas  volumes  to differ  from the
      reserve information prepared by Dyco and reviewed by Ryder Scott.




                                      -32-
<PAGE>


<TABLE>
<CAPTION>


                                      1999                      1998                     1997
                               --------------------      -------------------      --------------------
                                 Oil         Gas           Oil        Gas          Oil          Gas
                               (Bbls)       (Mcf)        (Bbls)      (Mcf)        (Bbls)       (Mcf)
                               -------    ---------      -------   ---------      -------    ---------
<S>                            <C>        <C>            <C>       <C>            <C>        <C>
Proved reserves,
   beginning of year            1,010      444,604        1,030     437,603        1,478      504,395

Revisions of previous
   estimates                      413       46,380          362      84,776       (   43)     101,511

Purchase of reserves              -         20,414           -          -             -           -

Sales of reserves                 -           -              -     (  3,296)          -           -

Production                     (  263)    ( 52,504)      (  382)   ( 74,479)      (  405)    (168,303)
                                -----      -------        -----     -------        -----      -------

Proved reserves,
   end of year                  1,160      458,894        1,010     444,604        1,030      437,603
                                =====      =======        =====     =======        =====      =======

Proved developed reserves:
   Beginning of year            1,010      444,604        1,030     437,603        1,478      504,395
                                -----      -------        -----     -------        -----      -------

   End of year                  1,160      458,894        1,010     444,604        1,030      437,603
                                =====      =======        =====     =======        =====      =======

</TABLE>



                                      -33-
<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;
      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.  The Program's reserves were determined at December
      31,  1999 using oil and gas prices of $22.75 per barrel and $2.24 per Mcf,
      respectively.


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, the General Partner.  The business address of such directors and executive
officers is Two West Second Street, Tulsa, Oklahoma 74103.

            NAME         AGE            POSITION WITH DYCO
      ----------------   ---     ------------------------------
      Dennis R. Neill    47      President and Director

      Patrick M. Hall    41      Chief Financial Officer

      Judy K. Fox        48      Secretary

      The  director   will  hold  office  until  the  next  annual   meeting  of
shareholders of Dyco or until his successor has been duly elected and qualified.
All executive officers serve at the discretion of the Board of Directors.

      Dennis R. Neill joined Samson in 1981, was named Senior Vice President and
Director of Dyco on June 18, 1991,  and was named  President of Dyco on June 30,
1996. Prior to joining Samson, he




                                      -34-
<PAGE>




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  of Samson  Investment  Company  and as  President  and  Director  of
Samson  Properties   Incorporated,   Samson  Hydrocarbons  Company,  Berry  Gas
Company, Circle L Drilling Company,  Compression,  Inc., and Geodyne Resources,
Inc. and its subsidiaries.

      Patrick M. Hall joined Samson in 1983,  was named a Vice President of Dyco
on June 18,  1991,  and was named  Chief  Financial  Officer of Dyco on June 30,
1996. Prior to joining Samson 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 also
serves as Senior Vice President - Controller of Samson Investment Company.

      Judy K. Fox  joined  Samson  in 1990 and was named  Secretary  of Dyco on
June 30, 1996.  Prior to joining  Samson,  she served as Gas  Contract  Manager
for Ely  Energy  Company.  Ms.  Fox is also  Secretary  of Berry  Gas  Company,
Circle L Drilling  Company,  Compression,  Inc., Samson  Hydrocarbons  Company,
Samson  Properties   Incorporated,   and  Geodyne   Resources,   Inc.  and  its
subsidiaries.


      Section 16(a) Beneficial Ownership Reporting Compliance

      To the best  knowledge  of the Program and Dyco,  there were no  officers,
directors,  or ten  percent  owners who were  delinquent  filers  during 1999 of
reports required under Section 16(a) of the Securities and Exchange Act of 1934.


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, 1999:




                                      -35-
<PAGE>



      Compensation/Reimbursement to Dyco and its affiliates
                 Three Years Ended December 31, 1999

Type of Compensation/Reimbursement(1)             Expense
-------------------------------------   ---------------------------
                                          1999      1998     1997
                                        --------   -------  -------
Compensation:
   Operations                              (2)       (2)      (2)

Reimbursements:
   General and Administrative,
      Geological, and Engineering
      Expenses and Direct Expenses(3)   $24,876    $24,876  $24,876
----------

(1)   The  authority  for  all of such  compensation  and  reimbursement  is the
      Program Agreement.  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 some 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)   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 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.

      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




                                      -36-
<PAGE>




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,  gas
marketing,   and  other  functions   directly   attributable  to  the  Program's
operations.   When  actual  costs  incurred   benefit  other   partnerships  and
affiliates,  the  allocation  of  costs  is  based  on the  relationship  of the
Program's reserves to the total reserves owned by all partnerships and reserves.
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, 1999:



                                      -37-
<PAGE>

<TABLE>
<CAPTION>

                              Salary Reimbursement
                       Three Years Ended December 31, 1999

                                                                 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>
Dennis R. Neill,
President(1)         1997      -          -          -         -            -          -          -
                     1998      -          -          -         -            -          -          -
                     1999      -          -          -         -            -          -          -

All Executive
Officers,
Directors,
and Employees
as a group(2)        1997    $14,681      -          -         -            -          -          -
                     1998    $14,722      -          -         -            -          -          -
                     1999    $15,194      -          -         -            -          -          -

----------
(1)   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. Neill.
(2)   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.

</TABLE>




                                      -38-
<PAGE>




      Samson  maintains  necessary  inventories of new and used field equipment.
Samson may have provided  some of this  equipment for wells in which the Program
has an interest. This equipment was 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 March 1, 2000 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 Resources Company                  1,209     (50.4%)

All directors, officers, and
   affiliates of Dyco as a group
   and Dyco (5 persons)                   1,209     (50.4%)


ITEM 13.   CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

      Certain affiliates of Dyco 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 such affiliates
also create potential conflicts of interest.  An affiliate of the Program owns a
significant  amount of the  Program's  Units and  therefore  has 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 Program Agreement 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 drilling partnerships.



                                      -39-
<PAGE>



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 Samson. The Program thus competes with Samson
(including  other  oil and gas  programs)  for the  time and  resources  of such
personnel.  Samson  devotes  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.  Because  affiliates of the Program who provide
services to the  Program  have  fiduciary  or other  duties to other  members of
Samson,  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 Samson. On the other hand,  management
believes that the Program's  negotiating strength and contractual positions have
been enhanced by virtue of its affiliation with Samson.

      Samson  Resources  Company,  an  affiliate  of  Dyco,  ("Resources")  owns
approximately  50.4% of the  Program's  outstanding  Units as of March 1,  2000,
making the Program a 50% subsidiary of Resources.  The Program Agreement permits
Resources to independently  vote its Units.  Resources'  majority Unit ownership
will  determine  the outcome of any matter  submitted  for a vote of the Limited
Partners.





                                      -40-
<PAGE>



                                    PART IV


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

      (a)  Financial Statements, Financial Statement Schedules, and Exhibits.

           (1)  Financial Statements: The following financial statements for the
                Program as of December 31, 1999 and 1998 and for the years ended
                December  31,  1999,  1998,  and 1997 are  filed as part of this
                report:

                     Report of Independent Accountants
                     Balance Sheets
                     Statements of Operations
                     Statements of Changes in Partners' Capital
                     Statements of Cash Flows
                     Notes to Financial Statements

           (2)  Financial Statement Schedules:

                     None.

           (3)  Exhibits:

                4.1  Drilling  Agreement  dated April 1, 1978 for Dyco  Drilling
                     Program  1978-1 by and between the Dyco Oil and Gas Program
                     1978-1, Dyco Petroleum Corporation,  and Jaye F. Dyer filed
                     as Exhibit  4.1 to Annual  Report on Form 10-K for the year
                     ended  December  31,  1991 on April 10,  1992 and is hereby
                     incorporated by reference.

                4.2  Program  Agreement dated April 1, 1978 for Dyco Oil and Gas
                     Program  1978-1 by and between Dyco  Petroleum  Corporation
                     and  Participants  filed as Exhibit 4.2 to Annual Report on
                     Form 10-K for the year ended December 31, 1991 on April 10,
                     1992 and is hereby incorporated by reference.

                4.3  Amendment to Program Agreement for Dyco Oil and Gas Program
                     1978-1  dated  February  9, 1989  filed as  Exhibit  4.3 to
                     Annual  Report on Form 10K for the year ended  December 31,
                     1991 on  April  10,  1992  and is  hereby  incorporated  by
                     reference.




                                      -41-
<PAGE>





                4.4  Certificate  of  Limited  Partnership  for Dyco Oil and Gas
                     Program 1978-1 Limited  Partnership filed as Exhibit 4.3 to
                     Annual Report on Form 10-K for the year ended  December 31,
                     1991 on  April  10,  1992  and is  hereby  incorporated  by
                     reference.

               *23.1 Consent of Ryder Scott  Company,  L.P. for Dyco Oil and Gas
                     Program 1978-1 Limited Partnership.

               *27.1 Financial  Data  Schedule   containing   summary  financial
                     information  extracted  from the  Dyco Oil and Gas  Program
                     1978-1  Limited  Partnership's  financial  statements as of
                     December 31, 1999 and for the year ended December 31, 1999.

                All other Exhibits are omitted as inapplicable.


                ------------------
                *  Filed herewith.


      (b)  Reports on Form 8-K filed during the fourth quarter of 1999:

                None.



                                      -42-
<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 1978-1
                               LIMITED PARTNERSHIP

                               By:  DYCO PETROLEUM CORPORATION
                                    General Partner

                                    March 16, 2000


                               By:  //s// Dennis R. Neill
                                    ------------------------------
                                    Dennis R. Neill
                                    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// Dennis R. Neill    President and        March 16, 2000
      -------------------      Director (Principal
          Dennis R. Neill      Executive Officer)

      //s// Patrick M. Hall    Chief Financial      March 16, 2000
      -------------------      Officer (Principal
          Patrick M. Hall      Financial and
                               Accounting Officer)

      //s// Judy K. Fox        Secretary            March 16, 2000
      -------------------
          Judy K. Fox




                                      -43-
<PAGE>



                          INDEX TO EXHIBITS


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

4.1             Drilling Agreement dated April 1, 1978 for Dyco Drilling Program
                1978-1 by and between the Dyco Oil and Gas Program 1978-1,  Dyco
                Petroleum Corporation,  and Jaye F. Dyer filed as Exhibit 4.1 to
                Annual Report on Form 10-K for the year ended  December 31, 1991
                on April 10, 1992 and is hereby incorporated by reference.

4.2             Program  Agreement  dated  April  1,  1978  for Dyco Oil and Gas
                Program  1978-1 by and between Dyco  Petroleum  Corporation  and
                Participants  filed as Exhibit 4.2 to Annual Report on Form 10-K
                for the year ended  December  31,  1991 on April 10, 1992 and is
                hereby incorporated by reference.

4.3             Amendment  to  Program  Agreement  for Dyco Oil and Gas  Program
                1978-1  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 10, 1992 and is hereby incorporated by reference.

4.4             Certificate of Limited  Partnership for Dyco Oil and Gas Program
                1978-1 Limited Partnership filed as Exhibit 4.3 to Annual Report
                on Form 10-K for the year ended  December  31, 1991 on April 10,
                1992 and is hereby incorporated by reference.

*23.1           Consent  of  Ryder  Scott  Company,  L.P.  for  Dyco Oil and Gas
                Program 1978-1 Limited Partnership.

*27.1           Financial Data Schedule containing summary financial information
                extracted  from  the  Dyco Oil and Gas  Program  1978-1  Limited
                Partnership's  financial  statements as of December 31, 1999 and
                for the year ended December 31, 1999.


------------------
*  Filed herewith.


                                      -44-