-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, Ffy1C+9nTpFmGMgjULNSuQiiZfvEtcGy3wgWCHXzRRHscjVxIYda3dWXanCQcFGG 4rnQTtiLnPCVlb3rr2VQRw== 0000215718-96-000026.txt : 19960402 0000215718-96-000026.hdr.sgml : 19960402 ACCESSION NUMBER: 0000215718-96-000026 CONFORMED SUBMISSION TYPE: 10-K405 PUBLIC DOCUMENT COUNT: 3 CONFORMED PERIOD OF REPORT: 19951231 FILED AS OF DATE: 19960214 SROS: NONE FILER: COMPANY DATA: COMPANY CONFORMED NAME: DYCO OIL & GAS PROGRAM 1979-1 LIMITED PARTNERSHIP CENTRAL INDEX KEY: 0000806573 STANDARD INDUSTRIAL CLASSIFICATION: 1381 IRS NUMBER: 411358013 STATE OF INCORPORATION: MN FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K405 SEC ACT: 1934 Act SEC FILE NUMBER: 033-10346-07 FILM NUMBER: 96519114 BUSINESS ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 BUSINESS PHONE: 9185831791 MAIL ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 FILER: COMPANY DATA: COMPANY CONFORMED NAME: DYCO OIL & GAS PROGRAM 1979-2 LIMITED PARTNERSHIP CENTRAL INDEX KEY: 0000806574 STANDARD INDUSTRIAL CLASSIFICATION: 1381 IRS NUMBER: 411358015 STATE OF INCORPORATION: MN FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-K SEC ACT: 1934 Act SEC FILE NUMBER: 033-10346-08 FILM NUMBER: 96519115 BUSINESS ADDRESS: STREET 1: SAMSON PLZ 2 W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 BUSINESS PHONE: 9185831791 MAIL ADDRESS: STREET 1: SAMSON PLZ STREET 2: TWO W SECOND ST CITY: TULSA STATE: OK ZIP: 74103 10-K 1 FORM 10-K SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 For the fiscal year ended December 31, 1995 Commission File Number 2-62275-03 (1979-1 Program) 2-62275-04 (1979-2 Program) DYCO 1979 OIL AND GAS PROGRAMS (TWO LIMITED PARTNERSHIPS) (Exact name of registrant as specified in its charter) 41-1358013 (1979-1 Program) Minnesota 41-1358015 (1979-2 Program) (State or other jurisdiction of (I.R.S. Employer incorporation or organization) Identification Number) Samson Plaza Two West Second Street Tulsa, Oklahoma 74103 (Address of principal (Zip Code) executive offices) Registrant's telephone number, including area code: (918) 583-1791 Securities registered pursuant to Section 12(b) of the Act: None. Securities registered pursuant to Section 12(g) of the Act: Units of limited partnership interest Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to the filing requirements for the past 90 days. Yes X No ----- ----- Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. Yes X No (Disclosure is contained herein) ----- ----- The units of limited partnership are not publicly traded, therefore, registrant cannot compute the aggregate market value of the voting units held by non-affiliates of the registrant. DOCUMENTS INCORPORATED BY REFERENCE: None. FORM 10-K DYCO 1979 OIL AND GAS PROGRAMS (Two Minnesota limited partnerships) TABLE OF CONTENTS PART I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 ITEM 1. BUSINESS . . . . . . . . . . . . . . . . . . . . . 1 ITEM 2. PROPERTIES . . . . . . . . . . . . . . . . . . . . 5 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 . . . . . . . . . . . . . 14 ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS . . . . . . . 16 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA . . . 23 ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE . . . . . . . 47 PART III . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47 ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT . . . . . . . . . . . . . . . . . . . . 47 ITEM 11. EXECUTIVE COMPENSATION . . . . . . . . . . . . . . 49 ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT . . . . . . . . . . . . . . . . . . 54 ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS . . 55 PART IV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56 ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K . . . . . . . . . . . . . . . 56 SIGNATURES . . . . . . . . . . . . . . . . . . . . . . . . . 59 ii PART I ITEM 1. BUSINESS General The Dyco Oil and Gas Program 1979-1 Limited Partnership (the "1979-1 Program") and Dyco Oil and Gas Program 1979-2 Limited Partnership (the "1979-2 Program") (collectively, the "Programs") are Minnesota limited partnerships engaged in the production of oil and gas. The 1979-1 Program and 1979-2 Program commenced operations on April 2, 1979 and July 2, 1979, respectively, with the primary financial objective of investing their limited partners' subscriptions in the drilling of oil and gas prospects and then distributing to their 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 Programs. See "Item 2. Properties" for a description of the Programs' reserves and properties. The limited partnership agreements for each of the Programs provide that limited partners are allocated 99% of all Program costs and revenues and that Dyco, as General Partner, is allocated 1% of all Program costs and revenues. Included in such costs is each Program's reimbursement to Dyco of the Program's proportionate share of Dyco's geological, engineering, and general and administrative expenses. Dyco serves as General Partner of 34 limited partnerships, including the Programs. Dyco is a wholly-owned subsidiary of Samson Natural Gas Company, which is a wholly-owned subsidiary of Samson Investment Company. Samson Investment Company and its various corporate subsidiaries, including Dyco, (collectively, the "Samson Companies") are engaged in the production and development of and exploration for oil and gas reserves and the acquisition and operation of producing properties. At December 31, 1995, the Samson Companies owned interests in approximately 18,000 oil and gas wells located in 19 states of the U.S. and 3 provinces of Canada. At December 31, 1995, the Samson Companies operated approximately 3,100 oil and gas wells located in 15 states of the U.S., 2 provinces of Canada, Venezuela, and Russia. As limited partnerships, the Programs have no officers, directors, or employees. They rely instead on the personnel of Dyco and the other Samson Companies. As of February 1, 1996 the Samson Companies employed approximately 830 persons. No employees are covered by collective bargaining agreements, and management believes that the Samson Companies provide a sound employee relations environment. For information regarding the executive officers of Dyco, see "Item 10. Directors and Executive Officers of the Registrant." 1 Dyco's and the Programs' principal place of business is located at Samson Plaza, Two West Second Street, Tulsa, Oklahoma 74103, and their telephone number is (918) 583-1791 or (800) 535-1791. Funding Although the Programs' partnership agreements permit the Programs to incur borrowings, each Program's operations and expenses are currently funded out of each Program's revenues from oil and gas sales. Dyco may, but is not required to, advance funds to each of the Programs for the same purposes for which Program borrowings are authorized. Principal Products Produced and Services Rendered The Programs' sole business is the development and production of oil and natural gas with a concentration on natural gas. The Programs do not hold any patents, trademarks, licenses, or concessions and are not a party to any government contracts. The Programs have no backlog of orders and do not participate in research and development activities. The Programs are not presently encountering shortages of oilfield tubular goods, compressors, production material, or other equipment. Oil, Gas, and Environmental Control Regulations Regulation of Production Operations -- The production of oil and gas is subject to extensive federal and state laws and regulations governing a wide variety of matters, including the drilling and spacing of wells, allowable rates of production, prevention of waste and pollution, and protection of the environment. In addition to the direct costs borne in complying with such regulations, operations and revenues may be impacted to the extent that certain regulations limit oil and gas production to below economic levels. Regulation of Sales and Transportation of Oil and Natural Gas -- Sales of crude oil and condensate are made by the Programs at market prices and are not subject to price controls. The sale of natural gas may be subject to both federal and state laws and regulations, including, but not limited to, the Natural Gas Act of 1938 (the "NGA"), the Natural Gas Policy Act of 1978 (the "NGPA"), and regulations promulgated by the Federal Energy Regulatory Commission (the "FERC") under the NGA, the NGPA, and other statutes. The provisions of the NGA and the NGPA, as well as the regulations thereunder, are complex and affect all who produce, resell, transport, or purchase natural gas, including the Programs. Although virtually all of the Programs' gas production is not subject to price regulation, 2 the NGA, NGPA, and FERC regulations affect the availability of gas transportation services and the ability of gas consumers to continue to purchase or use gas at current levels. Accordingly, such regulations may have a material effect on the Programs' operations and projections of future oil and gas production and revenues. Future Legislation -- Legislation affecting the oil and gas industry is under constant review for amendment or expansion. Because such laws and regulations are frequently amended or reinterpreted, management is unable to predict what additional energy legislation may be proposed or enacted or the future cost and impact of complying with existing or future regulations. Regulation of the Environment -- The Programs' operations are subject to numerous laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. Compliance with such laws and regulations, together with any penalties resulting from noncompliance therewith, may increase the cost of the Programs' operations or may affect the Programs' ability to complete, in a timely fashion, existing or future activities. Management anticipates that various local, state, and federal environmental control agencies will have an increasing impact on oil and gas operations. Significant Customers Purchases of gas by Premier Gas Company ("Premier") and Apache Corporation accounted for approximately 86.8% and 12.5%, respectively, of the 1979-1 Program's oil and gas sales during the year ended December 31, 1995. With respect to the 1979-2 Program, purchases of gas by Premier accounted for approximately 93.6% of its oil and gas sales during the year ended December 31, 1995. Premier was an affiliate of Dyco until December 6, 1995. See "Item 11. Executive Compensation." In the event of interruption of purchases by these significant customers or the cessation or material change in availability of open-access transportation by the Programs' pipeline transporters, the Programs may encounter difficulty in marketing their gas and in maintaining historic sales levels. Alternative purchasers or transporters may not be readily available. The Programs' principal customers for crude oil production are refiners and other companies which have pipeline facilities near the producing properties of the Programs. In the event pipeline facilities are not conveniently available to production areas, crude oil is usually trucked by purchasers to storage facilities. 3 Competition and Marketing The oil and gas industry is highly competitive, with a large number of companies and individuals engaged in the exploration and development of oil and gas properties. The ability of the Programs to produce and market oil and gas profitably depends on a number of factors that are beyond the control of the Programs. These factors include worldwide political instability (especially in oil-producing regions), the supply and price of foreign imports of oil and gas, the level of consumer product demand (which is heavily influenced by weather patterns), government regulations and taxes, the price and availability of alternative fuels, the overall economic environment, and the availability and capacity of transportation and processing facilities. The effect of these factors cannot be accurately predicted or anticipated. As a general rule, in recent years, worldwide oil production capacity and gas production capacity in certain areas of the United States exceeded demand and resulted in a decline in the average price of oil and gas in the United States. During the later part of 1994 and 1995, however, average oil prices in the United States increased. Oil prices increased from approximately $16.50 per barrel at Decem- ber 31, 1994 to approximately $18.50 per barrel at December 31, 1995. Management is unable to predict whether future oil prices will (i) stabilize, (ii) increase, or (iii) decrease. Gas sales contract prices have generally declined significantly since the mid-1980s due to a number of factors, including a nationwide surplus of gas and increased competition. Competition has increased among United States gas marketers due to the gas surplus, the partial deregulation of gas prices, the conversion by major pipelines to open access transportation, and the lack of strong residential demand for natural gas during the winter months for the last few years as a result of warm winters in much of the United States. However, spot gas prices in the areas where the Programs' gas is marketed increased during the later part of 1995 compared to prices received in the later part of 1994 and the first several months of 1995. Substantially all of the Programs' natural gas reserves are being sold in the "spot market." Due to the highly competitive nature of the spot market, prices on the spot market are subject to wide seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon the obtaining of transportation services provided by pipelines. The Programs' spot gas prices increased from approximately $1.67 per Mcf at December 31, 1994 to approximately $2.00 per Mcf at December 31, 1995. Such prices were on an MMBTU basis and differ from the prices actually received by the Programs due to transportation and marketing costs, BTU adjustments, and regional price and quality differences. Future prices will likely be different from (and may be lower than) the prices in effect on December 31, 1995. In many past years, year-end prices have tended to be higher, and in some cases 4 significantly higher, than the yearly average price actually received by the Programs for at least the year following the year-end valuation date. Management is unable to predict whether future gas prices will (i) stabilize, (ii) increase, or (iii) decrease. Insurance Coverage The Programs are 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 Programs maintain insurance coverage as is customary for entities of a similar size engaged in operations similar to that of the Programs, but losses can occur from uninsurable risks or in amounts in excess of existing insurance coverage. The occurrence of an event which is not fully covered by insurance could have a material adverse effect on the Programs' financial position and results of operations. ITEM 2. PROPERTIES Well Statistics The following table sets forth the numbers of gross and net productive wells of the Programs as of December 31, 1995. Well Statistics(1) As of December 31, 1995 1979-1 1979-2 Program Program ------- ------- Gross productive wells(2): Oil 3 - Gas 36 23 -- -- Total 39 23 Net productive wells(3): Oil .15 - Gas 1.78 1.63 ---- ---- Total 1.93 1.63 - - --------------- (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 5 for the well. Regardless of a well's oil or gas designation, it may produce oil, gas, or both oil and gas. (2) As used throughout this Annual Report, "Gross Well" refers to a well in which a working interest is owned. The number of gross wells is the total number of wells in which a working interest is owned. (3) As used throughout this Annual Report, "Net Well" refers to the sum of the fractional working interests owned in gross wells expressed as whole numbers and fractions thereof. For example, a 15% leasehold interest in a well represents one Gross Well, but 0.15 Net Well. Drilling Activities The Programs participated in no drilling activities for the year ended December 31, 1995. Oil and Gas Production, Revenue, and Price History The following table sets forth certain historical information concerning the oil (including condensates) and natural gas production, net of all royalties, overriding royalties, and other third party interests, of the Programs, revenues attributable to such production, and certain price and cost information. Net Production Data Year Ended December 31, -------------------------------- 1995 1994 1993 ---------- ---------- -------- 1979-1 Program: - - -------------- Production: Oil (Bbls)(1) 817 677 544 Gas (Mcf)(2) 286,965 242,706 369,956 Oil and gas sales: Oil $ 14,730 $ 10,885 $ 10,190 Gas 381,763 389,813 707,338 ------- --------- ------- Total $396,493 $ 400,698 $717,528 ======= ========= ======= Total direct operating expenses $118,370 $ 81,317 $ 88,763 ======= ========= ======= 6 Direct operating expenses as a percentage of oil and gas sales 29.9% 20.3% 12.4% Average sales price: Per barrel of oil $18.03 $16.08 $18.73 Per Mcf of gas 1.33 1.61 1.91 Direct operating expenses per equivalent Mcf of gas(3) $ .41 $ .33 $ .24 1979-2 Program: - - -------------- Production: Oil (Bbls)(1) 1,614 3,276 2,751 Gas (Mcf)(2) 313,765 574,279 485,686 Oil and gas sales: Oil $ 26,983 $ 51,648 $ 46,274 Gas 456,484 965,696 901,468 ------- --------- ------- Total $483,467 $1,017,344 $947,742 ======= ========= ======= Total direct operating expenses $103,957 $ 253,688 $213,988 ======= ========= ======= Direct operating expenses as a percentage of oil and gas sales 21.5% 24.9% 22.6% Average sales price: Per barrel of oil $16.72 $15.77 $16.82 Per Mcf of gas 1.45 1.68 1.86 Direct operating expenses per equivalent Mcf of gas(3) $ .32 $ .43 $ .43 - - --------------- (1) As used throughout this Annual Report, "Bbls" refers to barrels of 42 U.S. gallons and represents the basic unit for measuring the production of crude oil and condensate oil. (2) As used throughout this Annual Report, "Mcf" refers to volume of 1,000 cubic feet under prescribed conditions of pressure and temperature and represents the basic unit for measuring the production of natural gas. (3) Oil production is converted to gas equivalents at the rate of six Mcf per barrel, representing the estimated relative energy content of gas and oil, which rate is not necessarily indicative 7 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 Programs' estimated proved oil and gas reserves and net present value therefrom as of December 31, 1995. The schedule of quantities of proved oil and gas reserves was prepared by Dyco in accordance with the rules prescribed by the Securities and Exchange Commission (the "SEC"). As used throughout this Annual Report, "proved reserves" refers to those estimated quantities of crude oil, natural gas, and natural gas liquids which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known oil and gas reservoirs under existing economic and operating conditions. 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 Programs' proved reserves was calculated on the basis of current costs and prices at December 31, 1995. Such prices were not escalated except in certain circumstances where escalations were fixed and readily determinable in accordance with applicable contract provisions. The prices used by Dyco in calculating the net present value attributable to the Programs' proved reserves do not necessarily reflect market prices for oil and gas production subsequent to December 31, 1995. Furthermore, gas prices at December 31, 1995 were higher than the price used for determining the Programs' net present value of proved reserves for the year ended December 31, 1994. There can be no assurance that the prices used in calculating the net present value of the Programs' proved reserves at December 31, 1995 will actually be realized for such production. The process of estimating oil and gas reserves is complex, requiring significant subjective decisions in the evaluation of available geological, engineering, and economic data for each reservoir. The data for a given reservoir may change substantially over time as a result of, among other things, additional development activity, production history, and viability of production under varying economic conditions; consequently, it is reasonably possible that material revisions to existing reserve estimates may occur in the near future. Although every reasonable effort has been made to ensure that the reserve estimates reported herein represent the most accurate assessment possible, the significance of the subjective decisions required and variances in available data for various reservoirs make 8 these estimates generally less precise than other estimates presented in connection with financial statement disclosures. Proved Reserves and Net Present Value From Proved Reserves As of December 31, 1995 1979-1 Program: - - -------------- Estimated proved reserves: Natural gas (Mcf) 1,094,721 Oil and liquids (Bbls) 3,472 Net present value (discounted at 10% per annum) $1,170,057 1979-2 Program: - - -------------- Estimated proved reserves: Natural gas (Mcf) 1,137,576 Oil and liquids (Bbls) 13,652 Net present value (discounted at 10% per annum) $1,283,086 No estimates of the proved reserves of the Programs comparable to those included herein have been included in reports to any federal agency other than the SEC. Additional information relating to the Programs' proved reserves is contained in Notes 4 and 5 to the Programs' financial statements, included in Item 8 of this Annual Report. Significant Properties 1979-1 Program -------------- As of December 31, 1995, the 1979-1 Program's properties consisted of 39 gross (1.93 net) productive wells in which the 1979-1 Program owned a working interest. The 1979-1 Program owned a non- working interest in an additional 11 gross wells. Affiliates of the 1979-1 Program operate 10 (20%) of its total wells. As of December 31, 1995, the 1979-1 Program's net interests in its properties resulted in estimated total proved reserves of 1,094,721 9 Mcf of natural gas and 3,472 barrels of oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of $1,170,057. All of the 1979-1 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. 1979-2 Program -------------- As of December 31, 1995, the 1979-2 Program's properties consisted of 23 gross (1.63 net) productive wells in which the 1979-2 Program owned a working interest. The 1979-2 Program owned a non- working interest in an additional 2 gross wells. Affiliates of the 1979-2 Program operate 5 (20%) of its total wells. As of December 31, 1995, the 1979-2 Program's net interests in its properties resulted in estimated total proved reserves of 1,137,576 Mcf of natural gas and 13,652 barrels of oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of $1,283,086. Substantially all of the 1979-2 Program's reserves are located in the Anadarko Basin. All of the 1979-2 Program's properties are located onshore in the continental United States. As of December 31, 1995, the 1979-2 Program's properties in the Anadarko Basin consisted of 15 gross (1.27 net) wells in which the 1979-2 Program owned a working interest. The 1979-2 Program owned a non-working interest in an additional 2 gross wells. Affiliates of the 1979-2 Program operate 4 (24%) of its total wells in the Anadarko Basin. As of December 31, 1995, the 1979-2 Program's net interest in such wells resulted in estimated total proved reserves of approxi- mately 1,051,596 Mcf of natural gas and approximately 12,018 barrels of crude oil, with a present value (discounted at 10% per annum) of estimated future net cash flow of approximately $1,180,719. Title to Oil and Gas Properties Management believes that the Programs have satisfactory title to their oil and gas properties. Record title to substantially all of the Programs' properties is held by Dyco as nominee. Title to the Programs' 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 Programs' interest therein or materially interfere with their use in the operation of the Programs' business. 10 ITEM 3. LEGAL PROCEEDINGS On October 26, 1993, certain royalty owners filed a class action lawsuit against Dyco and another party in which they alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells, the Johnson No. 1-22. (Randy Beutler, et al. v. Dyco, et al., Case No. CJ-93-311, District Court of Custer County, Oklahoma). The 1979-2 Program has an approximate 2.6% working interest in the Johnson No. 1-22 well. The plaintiffs are alleging claims based on breach of contract, breach of fiduciary obligation, and unjust enrichment and are seeking an accounting and declaration as a third party beneficiary under the gas contract. The plaintiffs have not quantified the amount of their damages, but they are seeking exemplary damages, unpaid royalties, and interest. Dyco has filed its answer in the matter in which it denied all of the plaintiffs' allegations, and discovery is proceeding in the matter. On January 18, 1994 the district court certified the matter as a class action and on November 29, 1994 the plaintiffs filed a motion for summary judgment in the matter. Oral arguments were heard on the motion in January 1995, however, as of the date of this Annual Report, the district court has not ruled on the motion. Dyco intends to vigorously defend the lawsuit. As of the date of this Annual Report, management cannot determine the amount of any alleged damages which would be allocable to the 1979-2 Program from this lawsuit. On October 21, 1994 a royalty owner filed a class action lawsuit against Samson Resources Company and other parties in which the royalty owner alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells, the Guenzel No. 1 (T.W. Walbert v. Samson Resources Company, et al., Case No. CJ- 94-74, District Court of Dewey County, Oklahoma). The 1979-2 Program has a 1.08% working interest in the Guenzel No. 1 well. The plaintiffs are alleging claims based on unjust enrichment, breach of contract and fiduciary obligation, and constructive fraud, and are seeking an accounting. The plaintiffs have not quantified the amount of their damages, but they are seeking actual and punitive damages, interest, and costs. On November 17, 1994 the defendants filed a special appearance and motion to dismiss for lack of venue. The court then entered an order transferring venue to Oklahoma County District Court. Discovery is proceeding and Samson Resources Company intends to vigorously defend the lawsuit. As of the date of this Annual Report, management cannot determine the amount of any alleged damages which would be allocable to the 1979-2 Program from this lawsuit. Except for the foregoing, to the knowledge of the management of Dyco and the Programs, neither Dyco, the Programs, nor the Programs' properties are subject to any litigation, the results of which would 11 have a material effect on the Programs' or Dyco's financial condition or operations. ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF LIMITED PARTNERS There were no matters submitted to a vote of the limited partners of either Program during 1995. PART II ITEM 5. MARKET FOR THE REGISTRANT'S LIMITED PARTNERSHIP UNITS AND RELATED LIMITED PARTNER MATTERS The Programs do not have an established trading market for their units of limited partnership interest ("Units"). Pursuant to the terms of the Programs' limited partnership agreements, Dyco, as General Partner, is obligated to annually offer a repurchase offer which is based on the estimated future net revenues from the Programs' reserves and is calculated pursuant to the terms of the limited partnership agreement. Such repurchase offer is recalculated monthly in order to reflect cash distributions made to the limited partners and other extraordinary events. The following table sets forth, for the periods indicated, Dyco's repurchase offer per Unit and the amount of the Programs' cash distributions per Unit for the same period. For purposes of this Annual Report, a Unit represents an initial subscription of $5,000 to a Program. 1979-1 Program -------------- Repurchase Cash Price Distributions ---------- ------------- 1994: First Quarter $232 $20 Second Quarter 283 35 Third Quarter 263 20 Fourth Quarter 263 - 1995: First Quarter $263 35 Second Quarter 228 30 Third Quarter 229 - Fourth Quarter 229 - 1996: First Quarter $229 (1) --------------- (1) To be declared in March 1996. 12 1979-2 Program -------------- Repurchase Cash Price Distributions ---------- ------------- 1994: First Quarter $301 $ - Second Quarter 469 - Third Quarter 374 95 Fourth Quarter 304 70 1995: First Quarter $304 65 Second Quarter 239 40 Third Quarter 335 25 Fourth Quarter 310 25 1996: First Quarter $285 (1) --------------- (1) To be declared in March 1996. The 1979-1 Program has 3,172 Units outstanding and approximately 1,159 limited partners of record. The 1979-2 Program has 2,889 Units outstanding and approximately 878 limited partners of record. 13 ITEM 6. SELECTED FINANCIAL DATA
SELECTED FINANCIAL DATA The following table presents selected financial data for the Programs. This data should be read in conjunction with the financial statements of the Programs, and the respective notes thereto, included elsewhere in this Annual Report. See "Item 8. Financial Statements and Supplementary Data." 1979-1 Program -------------- December 31, ---------------------------------------------------- 1995 1994 1993 1992 1991 -------- -------- -------- ---------- ---------- Summary of Operations: Oil and gas sales $396,493 $400,698 $717,528 $ 909,666 $235,370 Total revenues 398,559 401,930 720,210 1,405,677 244,285 Lease operating expenses 90,080 52,310 37,565 61,391 103,209 Production taxes 28,290 29,007 51,198 64,842 16,514 General and administrative expenses 54,317 51,498 55,466 58,109 61,485 Depreciation, depletion, and amortization of oil and gas properties 54,252 70,054 103,973 156,925 94,306 Valuation allowance for oil and gas properties - - - - 640,800 Interest expense - - - 12,366 112,216 Net income (loss) 171,620 199,061 472,008 1,052,044 ( 784,245) per Unit 54 63 149 332 ( 247) Cash distributions 206,180 237,900 602,680 697,840 126,879 per Unit 65 75 190 220 40 Summary Balance Sheet Data: Total assets 467,816 483,352 489,362 620,617 664,858 Partners' capital 409,567 444,127 482,966 613,638 259,434
14
1979-2 Program -------------- December 31, ---------------------------------------------------------- 1995 1994 1993 1992 1991 -------- ---------- ---------- ---------- ------------ Summary of Operations: Oil and gas sales $483,467 $1,017,344 $ 947,742 $ 373,656 $ 391,378 Total revenues 490,205 1,025,628 1,037,181 1,065,329 511,985 Lease operating expenses 67,295 178,826 145,697 76,118 117,779 Production taxes 36,662 74,862 68,291 27,876 32,294 General and administrative expenses 40,709 37,993 42,565 44,708 47,104 Depreciation, depletion, and amortization of oil and gas properties 84,448 244,687 185,125 86,297 197,209 Valuation allowance for oil and gas properties - - - - 273,108 Interest expense - - - 18,402 129,382 Net income (loss) 261,091 489,260 595,503 811,928 ( 284,891) per Unit 90 169 206 281 ( 99) Cash distributions 447,795 476,685 1,820,070 173,340 187,785 per Unit 155 165 630 60 65 Summary Balance Sheet Data: Total assets 705,367 857,507 1,538,968 2,774,685 2,525,989 Partners' capital 662,591 849,295 836,720 2,061,287 1,422,699
15 ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS RESULTS OF OPERATIONS General ------- The following general discussion should be read in conjunction with the analysis of results of operations provided below. In management's view, it is not possible to predict accurately either the short-term or long-term prices for oil or gas. Specifically, due to the oversupply of natural gas in recent years, certain of the Programs' gas producing properties have suffered, and continue to suffer during portions of the year, production curtailments and seasonal reductions in the prices paid by purchasers. Additional curtailments and seasonal or regional price reductions will adversely affect the operations and financial condition of the Programs. Gas sales prices, which have generally declined significantly since the mid-1980s, increased during the fourth quarter of 1995. See "Item 1. Business - Competition and Marketing." Actual future prices received by the Programs will likely be different from (and may be lower than) the prices in effect on December 31, 1995. In many past years, year- end prices have tended to be higher, and in some cases significantly higher, than the yearly average price actually received by the Programs for at least the year following the year-end valuation date. Management is unable to predict whether future gas prices will (i) stabilize, (ii) increase, or (iii) decrease. The amount of the Programs' cash flow, however, is dependent on such future gas prices. 1979-1 Program -------------- Year Ended December 31, 1995 Compared to Year Ended December 31, 1994 ------------------------------------- Total oil and gas sales decreased slightly by 1.0% for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease resulted from a decrease in the average price of natural gas sold, partially offset by increases in the volumes of oil and natural gas sold and an increase in the average price of oil sold for the year ended December 31, 1995 as compared to the year ended December 31, 1994. Volumes of oil and natural gas sold increased 140 barrels and 44,259 Mcf, respectively, for the year ended December 31, 1995 as compared to the year ended December 31, 1994. The increase in volumes of natural gas sold was primarily a result of (i) significant positive prior period volume adjustments on two wells during the year ended December 31, 1995 and (ii) increased production on another well 16 during the year ended December 31, 1995 as compared to the year ended December 31, 1994 as a result of recent recompletion activities on the well. Average natural gas prices decreased to $1.33 per Mcf for the year ended December 31, 1995 from $1.61 per Mcf for the year ended December 31, 1994, while average oil prices increased to $18.03 per barrel for the year ended December 31, 1995 from $16.08 per barrel for the year ended December 31, 1994. Oil and gas production expenses (including lease operating expenses and production taxes) increased 45.6% for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase was primarily a result of workover charges incurred on one well during the year ended December 31, 1995 in order to improve the recovery of reserves and the increase in volumes of natural gas sold during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses increased to 29.9% for the year ended December 31, 1995 from 20.3% for the year ended December 31, 1994. This percentage increase was primarily a result of the dollar increase in oil and gas production expenses related to the workover charges discussed above and the decrease in the average price of natural gas sold for the year ended December 31, 1995 as compared to the similar period in 1994. Depreciation, depletion, and amortization of oil and gas properties decreased $15,802 for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease was primarily a result of a significant upward revision in the estimate of the 1979-1 Program's remaining natural gas reserves during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, this expense decreased to 13.7% for the year ended December 31, 1995 from 17.5% for the year ended December 31, 1994. This decrease was primarily a result of the dollar decrease in depreciation, depletion, and amortization discussed above. General and administrative expenses increased slightly by $2,819 for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase resulted primarily from an increase in professional fees and an increase in printing and postage fees during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses remained relatively stable, increasing only slightly to 13.7% for the year ended December 31, 1995 from 12.9% for the year ended December 31, 1994 due to the dollar increase in general and administrative expenses discussed above. 17 Year Ended December 31, 1994 Compared to Year Ended December 31, 1993 ------------------------------------- Total oil and gas sales decreased 44.2% for the year ended Decem- ber 31, 1994 as compared to the year ended December 31, 1993. This decrease was due primarily to a decrease in volumes of natural gas sold and decreases in the average prices of oil and natural gas sold. Volumes of natural gas sold decreased 127,250 Mcf for the year ended December 31, 1994 as compared to the year ended December 31, 1993, while volumes of oil sold increased slightly by 133 barrels for the year ended December 31, 1994 as compared to the year ended December 31, 1993. The decrease in volumes of natural gas sold was primarily a result of significant positive prior period volume adjustments from purchasers on several wells during the year ended December 31, 1993. Average oil and natural gas prices decreased to $16.08 per barrel and $1.61 per Mcf for the year ended December 31, 1994 from averages of $18.73 per barrel and $1.91 per Mcf for the year ended December 31, 1993. Oil and gas production expenses (including lease operating expenses and production taxes) decreased 8.4% for the year ended December 31, 1994 as compared to the year ended December 31, 1993. This decrease was primarily due to decreases in the volumes of natural gas sold and average prices of oil and natural gas sold, partially offset by an increase in lease operating expenses. The increase in lease operating expenses was due to abnormally low lease operating expenses in 1993. As a percentage of oil and gas sales, these expenses increased to 20.3% for the year ended December 31, 1994 from 12.4% for the year ended December 31, 1993. This percentage increase was primarily a result of the decrease in the average price of natural gas sold. Depreciation, depletion, and amortization of oil and gas properties decreased $33,919 for the year ended December 31, 1994 as compared to the year ended December 31, 1993. This decrease was primarily due to the decreased volumes of natural gas sold and significant upward revisions in the estimate of the 1979-2 Program's remaining gas reserves during 1994. As a percentage of oil and gas sales, this expense increased to 17.5% for the year ended December 31, 1994 from 14.5% for the year ended December 31, 1993. This increase was primarily a result of the decreases in average prices of oil and natural gas sold. General and administrative expenses decreased $3,968 for the year ended December 31, 1994 as compared to the year ended December 31, 1993. This decrease was primarily due to a decrease in professional fees during the year ended December 31, 1994 as compared to the similar period in 1993. As a percentage of oil and gas sales, these expenses increased to 12.9% for the year ended December 31, 1994 from 7.7% for the year ended December 31, 1993. 18 This percentage increase was primarily a result of the decrease in volumes and average price of natural gas sold. 1979-2 Program -------------- Year Ended December 31, 1995 Compared to Year Ended December 31, 1994 ------------------------------------- Total oil and gas sales decreased by 52.5% for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease resulted primarily from decreases in both (i) the volumes of oil and natural gas sold and (ii) the average price of natural gas sold during the year ended December 31, 1995 as compared to the year ended December 31, 1994. Volumes of oil and natural gas sold decreased 1,662 barrels and 260,514 Mcf, respectively, for the year ended December 31, 1995 as compared to the year ended December 31, 1994. The decreases in the volumes of oil and natural gas sold was primarily a result of significant positive prior period volume adjustments from various purchasers on several wells during the year ended December 31, 1994. Average natural gas prices decreased to $1.45 per Mcf for the year ended December 31, 1995 from $1.68 per Mcf for the year ended December 31, 1994, while the average price of oil sold increased to $16.72 per barrel for the year ended December 31, 1995 from $15.77 per barrel for the year ended December 31, 1994. Oil and gas production expenses (including lease operating expenses and production taxes) decreased 59.0% for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This decrease resulted primarily from (i) lower operating expenses due to decreased oil and natural gas production in 1995 and (ii) lower production taxes due to the decrease in oil and natural gas sales during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses decreased to 21.5% for the year ended December 31, 1995 from 24.9% for the year ended December 31, 1994. This percentage decrease was primarily a result of the dollar decrease discussed above, partially offset by the decrease in the average price of natural gas sold for the year ended December 31, 1995 as compared to the year ended December 31, 1994. Depreciation, depletion, and amortization of oil and gas properties decreased $160,239 for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This dollar decrease was primarily a result of (i) an upward revision in the estimate of the 1979-2 Program's remaining natural gas reserves at December 31, 1995 and (ii) the decreases in volumes of oil and natural gas sold during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, this expense 19 decreased to 17.5% for the year ended December 31, 1995 from 24.1% for the year ended December 31, 1994. This percentage decrease was primarily a result of the dollar decrease in depreciation, depletion, and amortization expense discussed above. General and administrative expenses increased $2,716 for the year ended December 31, 1995 as compared to the year ended December 31, 1994. This increase resulted primarily from an increase in professional fees and an increase in printing and postage fees during the year ended December 31, 1995 as compared to the year ended December 31, 1994. As a percentage of oil and gas sales, these expenses increased to 8.4% for the year ended December 31, 1995 from 3.7% for the year ended December 31, 1994. This percentage increase was primarily due to the dollar decrease in oil and gas sales. Year Ended December 31, 1994 Compared to Year Ended December 31, 1993 ------------------------------------- Total oil and gas sales remained relatively constant for the year ended December 31, 1994 as compared to the year ended December 31, 1993. While volumes of oil and natural gas sold increased for the year ended December 31, 1994 as compared to the year ended December 31, 1993, any resulting increase in oil and natural gas sales was offset by decreases in the average prices of oil and natural gas sold. Volumes of oil and natural gas sold increased 525 barrels and 88,593 Mcf, respectively, for the year ended December 31, 1994 as compared to the year ended December 31, 1994. The increase in volumes of natural gas sold was primarily due to significantly higher production on two wells during the year ended December 31, 1994. Average oil prices decreased to $15.77 per barrel for the year ended December 31, 1994 from $16.82 per barrel for the year ended December 31, 1993, while average natural gas prices decreased to $1.68 per Mcf for the year ended December 31, 1994 from $1.86 per Mcf for the year ended December 31, 1993. Oil and gas production expenses (including lease operating expenses and production taxes) increased 18.6% for the year ended December 31, 1994 as compared to the year ended December 31, 1993. However, such expenses per equivalent Mcf of gas were consistent between 1994 and 1993. As a percentage of oil and gas sales (excluded from oil and gas sales for this calculation and similar calculations as discussed below is the gas purchase contract settlement of $82,805 which was included in total revenues during the year ended December 31, 1993), these expenses increased slightly to 24.9% for the year ended December 31, 1994 from 22.6% for the year ended December 31, 1993. 20 Depreciation, depletion, and amortization of oil and gas properties increased $59,562 for the year ended December 31, 1994 as compared to the year ended December 31, 1993. This dollar increase was primarily due to the increase in volumes of oil and natural gas sold and decreases in year-end prices of natural gas of remaining gas reserves in 1994. As a percentage of oil and gas sales, this expense increased to 24.1% for the year ended December 31, 1994 from 19.5% for the year ended December 31, 1993. This percentage increase was primarily a result of the decreases in the average prices of oil and natural gas sold. General and administrative expenses decreased $4,572 for the year ended December 31, 1994 as compared to the year ended December 31, 1993. This dollar decrease was primarily due to a decrease in professional fees during the year ended December 31, 1994 as compared to the similar period in 1993. As a percentage of oil and gas sales, these expenses remained relatively constant at 3.7% for the year ended December 31, 1994 compared to 4.5% for the year ended December 31, 1993. Liquidity and Capital Resources Net proceeds from operations less necessary operating capital are distributed to the limited partners on a quarterly basis. See "Item 5. Market for the Registrant's Limited Partnership Units and Related Limited Partner Matters." The net proceeds from production are not reinvested in productive assets, except to the extent that producing wells are improved, or where methods are employed to permit more efficient recovery of reserves, thereby resulting in a positive economic impact. Assuming production levels for the year ended December 31, 1995, the 1979-1 Program's and 1979-2 Program's proved reserve quantities at December 31, 1995 would have a life of approximately 3.8 and 3.6 years, respectively, for gas reserves and 4.2 and 8.5 years, respectively, for oil reserves. The Programs' available capital from the limited partners' subscriptions has been spent on oil and gas drilling activities and there should be no further material capital resource commitments in the future. The Programs have no debt commitments. Cash for operational purposes will be provided by current oil and gas production. There can be no assurance as to the amount of the Programs' future cash distributions. The Programs' ability to make cash distributions depends primarily upon the level of available cash flow generated by the Programs' operating activities, which will be affected (either positively or negatively) by many factors beyond the control of the Programs, 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 21 properties declines) since the Programs are not replacing production through acquisitions of producing properties and drilling. The 1979-2 Program is involved in certain litigation, the outcome of which cannot presently be determined. In the event of an unfavorable outcome, the 1979-2 Program's liquidity and capital resources could be negatively impacted. See "Item 3. Legal Proceedings" for a further discussion of this litigation. 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 Programs in 1995. Oil and natural gas prices have fluctuated during recent years and generally have not followed the same pattern as inflation. See "Item 2. Properties - Oil and Gas Production, Revenue, and Price History." 22 ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA REPORT OF INDEPENDENT ACCOUNTANTS TO THE PARTNERS DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP We have audited the financial statements of the Dyco Oil and Gas Program 1979-1 Limited Partnership (a Minnesota limited partnership) as listed in Item 14(a) of this Form 10-K. These financial statements are the responsibility of the Program's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and dis- closures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Dyco Oil and Gas Program 1979-1 Limited Partnership at December 31, 1995 and 1994, and the results of its operations and cash flows for each of the three years in the period ended December 31, 1995, in conformity with generally accepted accounting principles. COOPERS & LYBRAND L.L.P. Tulsa, Oklahoma February 6, 1996 23 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Balance Sheets December 31, 1995 and 1994 ASSETS ------ 1995 1994 -------- -------- CURRENT ASSETS: Cash and cash equivalents $ 32,509 $ 83,662 Accounts receivable - Related Party - 13,447 Accrued oil and gas sales, including $64,832 and $44,294 due from related parties 74,181 45,523 ------- ------- Total current assets $106,690 $142,632 NET OIL AND GAS PROPERTIES, utilizing the full cost method 291,717 266,548 DEFERRED CHARGE 69,409 74,172 ------- ------- $467,816 $483,352 ======= ======= LIABILITIES AND PARTNERS' CAPITAL --------------------------------- CURRENT LIABILITIES: Accounts payable $ 6,802 $ 3,603 Gas imbalance payable 13,323 - ------- ------- Total current liabilities $ 20,125 $ 3,603 ACCRUED LIABILITY 38,124 35,622 PARTNERS' CAPITAL: General Partner, issued and outstanding, 32 Units 4,096 4,442 Limited Partners, issued and outstanding, 3,140 Units 405,471 439,685 ------- ------- Total Partners' Capital $409,567 $444,127 ------- ------- $467,816 $483,352 ======= ======= The accompanying notes are an integral part of these financial statements. 24 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Operations For the Years Ended December 31, 1995, 1994 and 1993 1995 1994 1993 -------- -------- -------- REVENUES: Oil and gas sales, including $344,098, $389,812, and $713,542 of sales to related parties $396,493 $400,698 $717,528 Interest 2,066 1,232 2,682 ------- ------- ------- $398,559 $401,930 $720,210 COSTS AND EXPENSES: Lease operating $ 90,080 $ 52,310 $ 37,565 Production taxes 28,290 29,007 51,198 Depreciation, depletion, and amortization of oil and gas properties 54,252 70,054 103,973 General and administrative 54,317 51,498 55,466 ------- ------- ------- $226,939 $202,869 $248,202 ------- ------- ------- NET INCOME $171,620 $199,061 $472,008 ======= ======= ======= GENERAL PARTNER (1%) - NET INCOME $ 1,716 $ 1,991 $ 4,720 ======= ======= ======= LIMITED PARTNERS (99%) - NET INCOME $169,904 $197,070 $467,288 ======= ======= ======= NET INCOME per Unit $ 54 $ 63 $ 149 ======= ======= ======= UNITS OUTSTANDING 3,172 3,172 3,172 ======= ======= ======= The accompanying notes are an integral part of these financial statements. 25 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Partners' Capital For the Three Years Ended December 31, 1995, 1994, and 1993 General Limited Partner Partners Total -------- ---------- ---------- Balances at December 31, 1992 $6,136 $607,502 $613,638 Cash distributions ( 6,026) ( 596,654) ( 602,680) Net income 4,720 467,288 472,008 ----- ------- ------- Balances at December 31, 1993 $4,830 $478,136 $482,966 Cash distributions ( 2,379) ( 235,521) ( 237,900) Net income 1,991 197,070 199,061 ----- ------- ------- Balances at December 31, 1994 $4,442 $439,685 $444,127 Cash distributions ( 2,062) ( 204,118) ( 206,180) Net income 1,716 169,904 171,620 ----- ------- ------- Balances at December 31, 1995 $4,096 $405,471 $409,567 ===== ======= ======= The accompanying notes are an integral part of these financial statements. 26 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Statements of Cash Flows For the Years Ended December 31, 1995, 1994, and 1993 1995 1994 1993 ---------- ---------- ---------- CASH FLOWS FROM OPERATING ACTIVITIES: Net income $171,620 $199,061 $472,008 Adjustments to reconcile net income to net cash provided by operating activities; Depreciation, depletion, and amortization of oil and gas properties 54,252 70,054 103,973 (Increase) decrease in accrued oil and gas sales ( 28,658) 44,405 27,027 (Increase) decrease in accounts receivable - Related Party 13,447 ( 13,447) - (Increase) decrease in deferred charge 4,763 ( 44,301)( 29,871) Increase (decrease) in accounts payable 3,199 ( 2,793)( 583) Increase in gas imbalance payable 13,323 - - Increase in accrued liability 2,502 35,622 - ------- ------- ------- Net cash provided by operating activities $234,448 $288,601 $572,554 ------- ------- ------- CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas properties ($ 81,982) ($ 8,295)($ 305) Retirements of oil and gas properties 2,561 7,483 4,466 ------- ------- ------- Net cash provided (used) by investing activities ($ 79,421) ($ 812) $ 4,161 ------- ------- ------- CASH FLOWS FROM FINANCING ACTIVITIES: Cash distributions ($206,180) ($237,900)($602,680) ------- ------- ------- Net cash used by financing activities ($206,180) ($237,900)($602,680) ------- ------- ------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ($ 51,153) $ 49,889 ($ 25,965) CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 83,662 33,773 59,738 ------- ------- ------- CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 32,509 $ 83,662 $ 33,773 ======= ======= ======= The accompanying notes are an integral part of these financial statements. 27 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP Notes to Financial Statements For the Years Ended December 31, 1995, 1994, and 1993 1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Organization and Nature of Operations The Dyco Oil and Gas Program 1979-1 Limited Partnership (the "Program"), a Minnesota limited partnership, commenced operations on April 2, 1979. Dyco Petroleum Corporation ("Dyco") is the General Partner of the Program. Affiliates of Dyco owned 1,135.63 (35.8%) of the Program's Units at December 31, 1995. The Program's sole business is the development and production of oil and natural gas with a concentration on natural gas. Substantially all of the Program's natural gas reserves are being sold regionally in the "spot market." Due to the highly competitive nature of the spot market, prices on the spot market are subject to wide seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon the obtaining of transportation services provided by pipelines. Cash and Cash Equivalents The Program considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. Cash equivalents are not insured, which cause the Program to be subject to risk. Credit Risk Accrued oil and gas sales which are due from a variety of oil and natural gas purchasers subject the Program to a concentration of credit risk. Some of these purchasers are discussed in Note 3 - Major Customers. Oil and Gas Properties Oil and gas operations are accounted for using the full cost method of accounting. All productive and non-productive costs associated with the acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs are depleted on the gross revenue method using estimates of proved reserves. The full cost amortization rates per equivalent Mcf of gas produced during the years ended December 31, 1995, 1994, and 1993 were $0.19, $0.28, and $0.28, respectively. In the event the unamortized cost of oil and gas properties being amortized 28 exceeds the full cost ceiling (as defined by the Securities and Exchange Commission) the excess is charged to expense in the year during which such excess occurs. In addition, the Securities and Exchange Commission rules provide that if prices decline subsequent to year end, any excess that results from these declines may also be charged to expense during the current year. Sales and abandonments of properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved oil and gas reserves. Deferred Charge The Deferred Charge at December 31, 1995 and 1994 represents costs deferred for lease operating expenses incurred in connection with the Program's underproduced gas imbalance position. At December 31, 1995, cumulative total gas sales volumes for underproduced wells were less than the Program's pro- rata share of total gas production from these wells by 248,512 Mcf, resulting in prepaid lease operating expenses of $69,409. At December 31, 1994, cumulative total gas sales volumes for underproduced wells were less than the Program's pro- rata share of total gas production from these wells by 285,824 Mcf, resulting in prepaid lease operating expenses of $74,172. Accrued Liability Accrued Liability represents charges accrued for lease operating expenses incurred in connection with the Program's overproduced gas imbalance position. At December 31, 1995, cumulative total gas sales volumes for overproduced wells exceeded the Program's pro-rata share of total gas production from these wells by 136,498 Mcf, resulting in accrued lease operating expenses of $38,124. At December 31, 1994, cumulative total gas sales volumes for overproduced wells exceeded the Program's pro-rata share of total gas production from these wells by 137,270 Mcf, resulting in accrued lease operating expenses of $35,622. Oil and Gas Sales and Gas Imbalance Payable The Program's oil and condensate production is sold, title passed, and revenue recognized at or near the Program's wells under short-term purchase contracts at prevailing prices in accordance with arrangements which are customary in the oil industry. Sales of natural gas applicable to the Program's interest in producing oil and gas leases are recorded as income when the gas is metered and title transferred pursuant to the 29 gas sales contracts covering the Program's interest in natural gas reserves. During such times as the Program's sales of gas exceed its pro rata ownership in a well, such sales are recorded as income unless total sales from the well have exceeded the Program's share of estimated total gas reserves underlying the property at which time such excess is recorded as a liability. At December 31, 1995, total sales exceeded the Program's share of estimated total gas reserves on one well by $13,323 (6,499 Mcf). At December 31, 1994, no such liability was recorded. Use of Estimates in Financial Statements The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Further, accrued oil and gas sales, the deferred charge, the gas imbalance payable, and the accrued liability all involve estimates which could materially differ from the actual amounts ultimately realized in the near term. Oil and gas reserves (see Note 4) also involve significant estimates which could materially differ from the actual amounts ultimately realized. Income Taxes Income or loss for income tax purposes is includable in the income tax returns of the partners. Accordingly, no recognition has been given to income taxes in the accompanying financial statements. 2. TRANSACTIONS WITH RELATED PARTIES Under the terms of the Program's partnership agreement, Dyco is entitled to receive a reimbursement for all direct expenses and general and administrative, geological, and engineering expenses it incurs on behalf of the Program. During the years ended December 31, 1995, 1994, and 1993, such expenses totaled $54,317, $51,498, and $55,466, respectively, of which $44,520, $44,520, and $44,091, were paid to Dyco and its affiliates. The Program had a receivable from a related party at December 31, 1994 of $13,447. Any interest related to this receivable for the year ended December 31, 1994 would be insignificant and has not been recorded. 30 Affiliates of the Program operate certain of the Program's properties. Their policy is to bill the Program for all customary charges and cost reimbursements associated with these activities, together with any compressor rentals, consulting, or other services provided. The Program sells gas at market prices to Premier Gas Company ("Premier") and other similar gas marketing firms. Such firms may then resell such gas to third parties at market prices. Premier was an affiliate of the Program until December 6, 1995. During 1995, 1994, and 1993, these sales totaled $344,098, $389,812, and $713,542, respectively. At December 31, 1995 and 1994 accrued oil and gas sales included $64,832 and $44,294, respectively, due from Premier. 3. MAJOR CUSTOMERS The following purchasers individually accounted for more than 10% of the combined oil and gas sales of the Program for the years ended December 31, 1995, 1994, and 1993: Purchaser 1995 1994 1993 --------- ----- ----- ---- Premier 86.8% 97.3% 99.4% Apache 12.5% - % - % In the event of interruption of purchases by these significant customers or the cessation or material change in availability of open-access transportation by the Program's pipeline transporters, the Program may encounter difficulty in marketing its gas and in maintaining historic sales levels. Alternative purchasers or transporters may not be readily available. 4. SUPPLEMENTAL OIL AND GAS INFORMATION The following supplemental information regarding the oil and gas activities of the Program is presented pursuant to the disclosure requirements promulgated by the Securities and Exchange Commission. Capitalized Costs The Program's capitalized costs and accumulated depreciation, depletion, amortization, and valuation allowance were as follows: 31 December 31, ---------------------------- 1995 1994 ------------- ------------- Proved properties $20,452,284 $20,372,863 Unproved properties, not subject to depreciation, depletion, and amortization - - ---------- ---------- $20,452,284 $20,372,863 Less accumulated depreciation, depletion, amortization, and valuation allowance ( 20,160,567) ( 20,106,315) ---------- ---------- Net oil and gas properties $ 291,717 $ 266,548 ========== ========== Costs Incurred Costs incurred by the Program in connection with its oil and gas property acquisition, exploration, and development activities were as follows: December 31, ----------------------- 1995 1994 1993 ------- ------ ------ Acquisition of properties $ - $ - $ - Exploration costs - - - Development costs 81,982 8,295 305 ------ ----- ----- Total costs incurred $81,982 $8,295 $ 305 ====== ===== ===== 32
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 natural gas reserves for the years ended December 31, 1995, 1994, and 1993. Proved reserves were estimated by petroleum engineers employed by affiliates of Dyco. All of the Program's reserves are located in the United States. 1995 1994 1993 -------------------- -------------------- -------------------- Oil Gas Oil Gas Oil Gas (Bbls) (Mcf) (Bbls) (Mcf) (Bbls) (Mcf) ------- ----------- ------- ----------- ------- ----------- Proved reserves, beginning of year 2,272 1,010,914 2,583 1,113,662 2,831 1,274,478 Revisions of previous estimates 2,017 370,888 366 139,958 277 202,963 Sales of reserves - ( 116) - - - - Extensions and discoveries - - - - 19 6,177 Production ( 817) ( 286,965) ( 677) ( 242,706) ( 544) ( 369,956) ----- --------- ----- --------- ----- --------- Proved reserves, end of year 3,472 1,094,721 2,272 1,010,914 2,583 1,113,662 ===== ========= ===== ========= ===== ========= Proved developed reserves: Beginning of year 2,272 993,763 2,583 1,095,961 2,831 1,256,941 ----- --------- ----- --------- ----- --------- End of year 3,236 1,034,732 2,272 993,763 2,583 1,095,961 ===== ========= ===== ========= ===== =========
33 The process of estimating oil and gas reserves is complex, requiring significant subjective decisions in the evaluation of available geological, engineering, and economic data for each reservoir. The data for a given reservoir may change substantially over time as a result of, among other things, additional development activity, production history, and viability of production under varying economic conditions; con- sequently, it is reasonably possible that material revisions to existing reserve estimates may occur in the near future. Although every reasonable effort has been made to ensure that the reserve estimates reported herein represent the most accurate assessment possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. 34 REPORT OF INDEPENDENT ACCOUNTANTS TO THE PARTNERS DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP We have audited the financial statements of the Dyco Oil and Gas Program 1979-2 Limited Partnership (a Minnesota limited partnership) as listed in Item 14(a) of this Form 10-K. These financial statements are the responsibility of the Program's management. Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and dis- closures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion. In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Dyco Oil and Gas Program 1979-2 Limited Partnership at December 31, 1995 and 1994, and the results of its operations and cash flows for each of the three years in the period ended December 31, 1995, in conformity with generally accepted accounting principles. COOPERS & LYBRAND L.L.P. Tulsa, Oklahoma February 6, 1996 35 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Balance Sheets December 31, 1995 and 1994 ASSETS ------ 1995 1994 -------- -------- CURRENT ASSETS: Cash and cash equivalents $105,766 $129,666 Accrued oil and gas sales, including $71,862 and $125,752 due from related parties 91,623 149,136 ------- ------- Total current assets $197,389 $278,802 NET OIL AND GAS PROPERTIES, utilizing the full cost method 440,361 521,263 DEFERRED CHARGE 67,617 57,442 ------- ------- $705,367 $857,507 ======= ======= LIABILITIES AND PARTNERS' CAPITAL --------------------------------- CURRENT LIABILITIES: Accounts payable $ 6,417 $ 5,876 Gas imbalance payable 36,359 2,336 ------- ------- Total current liabilities $ 42,776 $ 8,212 CONTINGENCIES (Note 4) PARTNERS' CAPITAL: General Partner, issued and outstanding, 29 Units 6,626 8,493 Limited Partners, issued and outstanding, 2,860 Units 655,965 840,802 ------- ------- Total Partners' Capital $662,591 $849,295 ------- ------- $705,367 $857,507 ======= ======= The accompanying notes are an integral part of these financial statements. 36 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Operations For the Years Ended December 31, 1995, 1994 and 1993 1995 1994 1993 ---------- ---------- ---------- REVENUES: Oil and gas sales, including $452,687, $909,037, and $543,562 of sales to related parties $ 483,467 $1,017,344 $ 947,742 Interest 6,738 8,284 6,634 Other - - 82,805 --------- --------- --------- $ 490,205 $1,025,628 $1,037,181 COSTS AND EXPENSES: Lease operating $ 67,295 $ 178,826 $ 145,697 Production tax 36,662 74,862 68,291 Depreciation, depletion, and amortization of oil and gas properties 84,448 244,687 185,125 General and administrative 40,709 37,993 42,565 --------- --------- --------- $ 229,114 $ 536,368 $ 441,678 --------- --------- --------- NET INCOME $ 261,091 $ 489,260 $ 595,503 ========= ========= ========= GENERAL PARTNER (1%) - NET INCOME $ 2,611 $ 4,893 $ 5,955 ========= ========= ========= LIMITED PARTNERS (99%) - NET INCOME $ 258,480 $ 484,367 $ 589,548 ========= ========= ========= NET INCOME per Unit $ 90 $ 169 $ 206 ========= ========= ========= UNITS OUTSTANDING 2,889 2,889 2,889 ========= ========= ========= The accompanying notes are an integral part of these financial statements. 37 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Partners' Capital For the Three Years Ended December 31, 1995, 1994, and 1993 General Limited Partner Partners Total --------- ------------ ------------ Balances at Dec. 31, 1992 $20,613 $2,040,674 $2,061,287 Cash distributions ( 18,201) ( 1,801,869) ( 1,820,070) Net income 5,955 589,548 595,503 ------ --------- --------- Balances at Dec. 31, 1993 $ 8,367 $ 828,353 $ 836,720 Cash distributions ( 4,767) ( 471,918) ( 476,685) Net income 4,893 484,367 489,260 ------ --------- --------- Balances at Dec. 31, 1994 $ 8,493 $ 840,802 $ 849,295 Cash distributions ( 4,478) ( 443,317) ( 447,795) Net income 2,611 258,480 261,091 ------ --------- --------- Balances at Dec. 31, 1995 $ 6,626 $ 655,965 $ 662,591 ====== ========= ========= The accompanying notes are an integral part of these financial statements. 38 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Statements of Cash Flows For the Years Ended December 31, 1995, 1994, and 1993 1995 1994 1993 ---------- ---------- ------------ CASH FLOWS FROM OPERATING ACTIVITIES: Net income $261,091 $489,260 $ 595,503 Adjustments to reconcile net income to net cash provided by operating activities; Depreciation, depletion, and amortization of oil and gas properties 84,448 244,687 185,125 (Increase) decrease in accrued oil and gas sales 57,513 30,202 ( 78,920) Decrease in related party receivable - - 1,262,234 (Increase) decrease in deferred charge ( 10,175) 103,937 74,190 Increase (decrease) in payable to General Partner - ( 696,695) 225,746 Increase (decrease) in accounts payable 541 323 ( 1,513) Increase (decrease) in gas imbalance payable 34,023 2,336 ( 9,637) Decrease in gas prepayment - - ( 225,746) ------- ------- --------- Net cash provided by operating activities $427,441 $174,050 $2,026,982 ------- ------- --------- CASH FLOWS FROM INVESTING ACTIVITIES: Additions to oil and gas properties ($ 3,546) ($ 1,211) ($ 1,168) Retirements of oil and gas properties - - 49 ------- ------- --------- Net cash used by investing activities ($ 3,546) ($ 1,211) ($ 1,119) ------- ------- --------- CASH FLOWS FROM FINANCING ACTIVITIES: Cash distributions ($447,795) ($476,685) ($1,820,070) ------- ------- --------- Net cash used by financing activities ($447,795) ($476,685) ($1,820,070) ------- ------- --------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS ($ 23,900) ($303,846) $ 205,793 CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 129,666 433,512 227,719 ------- ------- --------- CASH AND CASH EQUIVALENTS AT END OF PERIOD $105,766 $129,666 $ 433,512 ======= ======= ========= The accompanying notes are an integral part of these financial statements. 39 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP Notes to Financial Statements For the Years Ended December 31, 1995, 1994, and 1993 1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Organization and Nature of Operations The Dyco Oil and Gas Program 1979-2 Limited Partnership (the "Program"), a Minnesota limited partnership, commenced operations on July 2, 1979. Dyco Petroleum Corporation ("Dyco") is the General Partner of the Program. Affiliates of Dyco owned 1,117.98 (38.7%) of the Program's Units at December 31, 1995. The Program's sole business is the development and production of oil and natural gas with a concentration on natural gas. Substantially all of the Program's natural gas reserves are being sold regionally in the "spot market." Due to the highly competitive nature of the spot market, prices on the spot market are subject to wide seasonal and regional pricing fluctuations. In addition, such spot market sales are generally short-term in nature and are dependent upon the obtaining of transportation services provided by pipelines. Cash and Cash Equivalents The Program considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. Cash equivalents are not insured, which cause the Program to be subject to risk. Credit Risk Accrued oil and gas sales which are due from a variety of oil and natural gas purchasers subject the Program to a concentration of credit risk. Some of these purchasers are discussed in Note 3. Major Customers. Oil and Gas Properties Oil and gas operations are accounted for using the full cost method of accounting. All productive and non-productive costs associated with the acquisition, exploration, and development of oil and gas reserves are capitalized. Capitalized costs are depleted on the gross revenue method using estimates of proved reserves. The full cost amortization rates per equivalent Mcf of gas produced during the years ended December 31, 1995, 1994, and 1993 were $0.26, $0.41, and $0.37, respectively. In the event 40 the unamortized cost of oil and gas properties being amortized exceeds the full cost ceiling (as defined by the Securities and Exchange Commission) the excess is charged to expense in the year during which such excess occurs. In addition, the Securities and Exchange Commission rules provide that if prices decline subsequent to year end, any excess that results from these declines may also be charged to expense during the current year. Sales and abandonments of properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved oil and gas reserves. Deferred Charge The Deferred Charge at December 31, 1995 and 1994 represents costs deferred for lease operating expenses incurred in connection with the Program's underproduced gas imbalance position. At December 31, 1995, cumulative total gas sales volumes for underproduced wells were less than the Program's pro- rata share of total gas production from these wells by 319,409 Mcf, resulting in prepaid lease operating expenses of $67,617. At December 31, 1994, cumulative total gas sales volumes for underproduced wells were less than the Program's pro-rata share of total gas production from these wells by 443,566 Mcf, resulting in prepaid lease operating expenses of $57,442. Oil and Gas Sales and Gas Imbalance Payable The Program's oil and condensate production is sold, title passed, and revenue recognized at or near the Program's wells under short-term purchase contracts at prevailing prices in accordance with arrangements which are customary in the oil industry. Sales of natural gas applicable to the Program's interest in producing oil and gas leases are recorded as income when the gas is metered and title transferred pursuant to the gas sales contracts covering the Program's interest in natural gas reserves. During such times as the Program's sales of gas exceed its pro rata ownership in a well, such sales are recorded as income unless total sales from the well have exceeded the Program's share of estimated total gas reserves underlying the property at which time such excess is recorded as a liability. At December 31, 1995, total sales exceeded the Program's share of estimated total gas reserves on one well by $36,359 (17,070 Mcf). At December 31, 1994, total sales exceeded the Program's share of estimated total gas reserves on one well by $2,336 (1,442 Mcf). 41 Payable to General Partner The payable to General Partner at December 31, 1993 primarily consisted of a liability owed to the General Partner related to the reallocation of gas volumes under the provisions of certain contracts. In addition, the payable to General Partner as of December 31, 1993 included an amount paid by the General Partner on behalf of the Program related to a gas prepayment contract settlement. The Program repaid the General Partner in 1994. Use of Estimates in Financial Statements The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Further, accrued oil and gas sales, the deferred charge, the gas imbalance payable, and the accrued liability all involve estimates which could materially differ from the actual amounts ultimately realized in the near term. Contingent liabilities from litigation (see Note 4) and 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. 2. TRANSACTIONS WITH RELATED PARTIES Under the terms of the Program's partnership agreement, Dyco is entitled to receive a reimbursement for all direct expenses and general and administrative, geological, and engineering expenses it incurs on behalf of the Program. During the years ended December 31, 1995, 1994, and 1993, such expenses totaled $40,709, $37,993, and $42,565, respectively, of which $31,212, $31,212, and $30,912 were paid 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 42 activities, together with any compressor rentals, consulting, or other services provided. The Program has sold gas to Premier Gas Company ("Premier") and other similar gas marketing firms. Such firms may then resell such gas to third parties at market prices. Premier was an affiliate of the Program until December 6, 1995. During 1995, 1994, and 1993, these sales totaled $452,687, $909,037, and $543,562, respectively. At December 31, 1995 and 1994 accrued oil and gas sales included $71,862 and $125,752, respectively, due from Premier. 3. MAJOR CUSTOMERS The following purchaser individually accounted for more than 10% of the combined oil and gas sales for the years ended December 31, 1995, 1994, and 1993: Purchaser 1995 1994 1993 --------- ----- ----- ----- Premier 93.6% 89.4% 57.4% In the event of interruption of purchases by this significant customer or the cessation or material change in availability of open-access transportation by the Program's pipeline transporters, the Program may encounter difficulty in marketing its gas and in maintaining historic sales levels. Alternative purchasers or transporters may not be readily available. 4. CONTINGENCIES On October 26, 1993, certain royalty owners filed a class action lawsuit against Dyco and another party in which they alleged entitlement to a share of the proceeds from a gas contract involving one of the Program's wells. The plaintiffs are alleging claims based on breach of contract, breach of fiduciary obligation, and unjust enrichment and are seeking an accounting and declaration as a third party beneficiary under the gas contract. The plaintiffs have not quantified the amount of their damages, but they are seeking exemplary damages, unpaid royalties, and interest. Dyco has filed its answer in the matter in which it denied all of the plaintiffs' allegations and discovery is proceeding in the matter. On January 18, 1994 the district court certified the matter as a class action and on November 29, 1994 the plaintiffs filed a motion for summary judgment in the matter. Oral arguments were heard on the motion in January 1995, however, as of the date of these financial statements, the district court has not ruled on the motion. Dyco 43 intends to vigorously defend the lawsuit. As of the date of these financial statements, management cannot determine the amount of any alleged damages which would be allocable to the Program from this lawsuit; however, it is reasonably possible that events could change in the future resulting in a material liability to the Program. On October 21, 1994 a royalty owner filed a class action lawsuit against Samson Resources Company and other parties in which he alleged entitlement to a share of the proceeds from a gas contract involving one of the 1979-2 Program's wells. The plaintiffs are alleging claims based on unjust enrichment, breach of contract and fiduciary obligation, and constructive fraud, and are seeking an accounting. The plaintiffs have not quantified the amount of their damages, but they are seeking actual and punitive damages, interest, and costs. On November 17, 1994 the defendants filed a special appearance and motion to dismiss for lack of venue. The court then entered an order transferring venue to Oklahoma County District Court. Discovery is proceeding and Samson Resources Company intends to vigorously defend the lawsuit. As of the date of these financial statements, management cannot determine the amount of any alleged damages which would be allocable to the 1979-2 Program from this lawsuit; however, it is reasonably possible that events could change in the future resulting in a material liability to the Program. 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 Securities and Exchange Commission. Capitalized Costs The Program's capitalized costs and accumulated depreciation, depletion, amortization, and valuation allowance were as follows: 44 December 31, ---------------------------- 1995 1994 ------------- ------------- Proved properties $18,562,544 $18,558,998 Unproved properties, not subject to depreciation, depletion, and amortization - - ---------- ---------- $18,562,544 $18,558,998 Less accumulated depreciation, depletion, amortization, and valuation allowance ( 18,122,183) ( 18,037,735) ---------- ---------- Net oil and gas properties $ 440,361 $ 521,263 ========== ========== Costs Incurred Costs incurred by the Program in connection with its oil and gas property acquisition, exploration, and development activities were as follows: December 31, -------------------------- 1995 1994 1993 ------ ------ ------ Acquisition of properties $ - $ - $ - Exploration costs - - - Development costs 3,546 1,211 1,168 ----- ----- ----- Total costs incurred $3,546 $1,211 $1,168 ===== ===== ===== 45
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 natural gas reserves for the years ended December 31, 1995, 1994, and 1993. Proved reserves were estimated by petroleum engineers employed by affiliates of the Program. All of the Program's reserves are located in the United States. 1995 1994 1993 -------------------- -------------------- -------------------- Oil Gas Oil Gas Oil Gas (Bbls) (Mcf) (Bbls) (Mcf) (Bbls) (Mcf) -------- ----------- ------- ----------- ------- ----------- Proved reserves, beginning of year 8,440 1,296,960 6,870 1,702,349 8,424 1,817,373 Revisions of previous estimates 6,826 154,381 4,846 168,890 1,197 370,662 Sales of reserves - - - - - - Extensions and discoveries - - - - - - Production ( 1,614) ( 313,765) (3,276) ( 574,279) (2,751) ( 485,686) ------ --------- ----- --------- ----- --------- Proved reserves, end of year 13,652 1,137,576 8,440 1,296,960 6,870 1,702,349 ====== ========= ===== ========= ===== ========= Proved developed reserves: Beginning of year 5,447 1,274,078 6,001 1,679,239 6,059 1,793,741 ------ --------- ----- --------- ----- --------- End of year 5,476 1,090,483 5,447 1,274,078 6,001 1,679,239 ====== ========= ===== ========= ===== =========
46 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 substan- tially 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. 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 Programs are limited partnerships and have no directors or executive officers. The following individuals are directors and executive officers of Dyco, which serves as the General Partner. The business address of such directors and executive officers is Two West Second Street, Tulsa, Oklahoma 74103. NAME AGE POSITION WITH GENERAL PARTNERS ---------------- --- -------------------------------- C. Philip Tholen 47 Chief Executive Officer, Presi- dent, and Chairman of the Board of Directors Dennis R. Neill 43 Senior Vice President and Director Jack A. Canon 46 Senior Vice President - General Counsel and Director Patrick M. Hall 37 Senior Vice President - Controller Annabel M. Jones 42 Secretary Judy F. Hughes 49 Treasurer 47 The directors will hold office until the next annual meeting of shareholders of Dyco and until their successors have been duly elected and qualified. All executive officers serve at the discretion of the Board of Directors. C. Philip Tholen joined the Samson Companies in 1977 and has served as President, Chief Executive Officer, and Director of Dyco since June 18, 1991. Prior to joining the Samson Companies, he was an audit manager for Arthur Andersen & Co. in Tulsa where he specialized in oil and natural gas industry audits and contract audits. He holds a Bachelor of Science degree in accounting from the University of Tulsa and is a Certified Public Accountant. Mr. Tholen is also Executive Vice President, Chief Financial Officer, Treasurer, and Director of Samson Investment Company; President and Chairman of the Board of Directors of Samson Natural Gas Company, Geodyne Resources, Inc. and its subsidiaries, and Samson Resources Company; President of two Divisions of Samson Natural Gas Company, Samson Exploration Company and Samson Production Services Company; Senior Vice President, Treasurer, and Director of Samson Properties Incorporated; and Director of Circle L Drilling Company and Samson Industrial Corporation. Dennis R. Neill joined the Samson Companies in 1981 and was named Senior Vice President and Director of Dyco on June 18, 1991. Prior to joining the Samson Companies, he was associated with a Tulsa law firm, Conner and Winters, where his principal practice was in the securities area. He received a Bachelor of Arts degree in political science from Oklahoma State University and a Juris Doctorate degree from the University of Texas. Mr. Neill also serves as Senior Vice President, Chief Operating Officer, and Director of Samson Properties Incorporated; Senior Vice President of Samson Hydrocarbons Company; Senior Vice President and Director of Geodyne Resources, Inc. and its subsidiaries; and President and Chairman of the Board of Directors of Samson Securities Company. Jack A. Canon joined the Samson Companies in 1983 and has served as a Vice President and Director of Dyco since June 18, 1991. Prior to joining the Samson Companies, he served as a staff attorney for Terra Resources, Inc. and was associated with the Tulsa law firm of Dyer, Powers, Marsh, Turner and Armstrong. He received a Bachelor of Science degree in accounting from Quincy College and a Juris Doctorate degree from the University of Tulsa. Mr. Canon also serves as Secretary of Samson Investment Company; Director of Samson Natural Gas Company, Samson Properties Incorporated, Circle L Drilling Company, and Samson Securities Company; Senior Vice President - General Counsel of Samson Production Services Company, a Division of Samson Natural Gas Company, and Geodyne Resources, Inc. and its subsidiaries; and Vice President - General Counsel of Samson Industrial Corporation. Patrick M. Hall joined the Samson Companies in 1983 and was named a Vice President of Dyco on June 18, 1991. Prior to joining the 48 Samson Companies he was a senior accountant with Peat Marwick Main & Co. in Tulsa. He holds a Bachelor of Science degree in accounting from Oklahoma State University and is a Certified Public Accountant. Mr. Hall is also a Director of Samson Natural Gas Company and Geodyne Resources, Inc. and its subsidiaries; Senior Vice President - Controller and Director of Samson Properties Incorporated; and Senior Vice President - Controller of Samson Production Services Company, a Division of Samson Natural Gas Company. Annabel M. Jones joined the Samson Companies in 1982 and was named Secretary of Dyco on June 18, 1991. Prior to joining the Samson Companies she served as associate general counsel of the Oklahoma Securities Commission. She holds Bachelor of Arts in political science and Juris Doctorate degrees from the University of Oklahoma. Ms. Jones serves as Assistant General Counsel - Corporate Affairs for Samson Production Services Company, a Division of Samson Natural Gas Company, and is also Secretary of Samson Properties Incorporated, Samson Natural Gas Company, Geodyne Resources, Inc. and its subsidiaries, and Samson Industrial Corporation; Vice-President, Secretary, and Director of Samson Securities Company; and Assistant Secretary of Samson Investment Company. Judy F. Hughes joined the Samson Companies in 1978 and was named Treasurer of Dyco on June 18, 1991. Prior to joining the Samson Companies, she performed treasury functions with Reading & Bates Corporation. She attended the University of Tulsa and also serves as Treasurer of Samson Natural Gas Company, Geodyne Resources, Inc. and its subsidiaries, and Samson Securities Company and Assistant Treasurer of Samson Investment Company and Samson Industrial Corporation. ITEM 11. EXECUTIVE COMPENSATION The Programs are limited partnerships and, therefore, have no officers or directors. The following table summarizes the amounts paid by the Programs as compensation and reimbursements to Dyco and its affiliates for the three years ended December 31, 1995: 49 Compensation/Reimbursement to Dyco and its affiliates Three Years Ended December 31, 1995 Type of Compensation/Reimbursement(1) Expense - - ------------------------------------- ------------------------- 1995 1994 1993 ------- ------- ------- 1979-1 Program - - -------------- Compensation: Operations $ (2) $ (2) $ (2) Gas Marketing $ (3) $ (3) $ (3) Reimbursements: General and Administrative, Geological, and Engineering Expenses and Direct Expenses(4) $44,520 $44,520 $44,091 1979-2 Program - - -------------- Compensation: Operations $ (2) $ (2) $ (2) Gas Marketing $ (3) $ (3) $ (3) Reimbursements: General and Administrative, Geological, and Engineering Expenses and Direct Expenses(4) $31,212 $31,212 $30,912 - - --------------- (1) The authority for all of such compensation and reimbursement is the limited partnership agreements of the Programs. 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 Programs serve as operator of some of the Programs' 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 Programs to such affiliates is impossible to quantify as of the date of this Annual Report. (3) Premier, an affiliate of the Programs until December 6, 1995, purchased a portion of the Programs' gas at market prices and resold such gas at market prices directly to end-users and local 50 distribution companies. For the years ended December 31, 1995, 1994, and 1993, the 1979-1 Program sold $344,098, $389,812, and $713,542, respectively, of gas to Premier. For the years ended December 31, 1995, 1994, and 1993, the 1979-2 Program sold $452,687, $909,037, and $543,562, respectively, of gas to Premier. (4) The Programs reimburse 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 Programs. The directors, officers, and employees of Dyco and its affiliates receive no direct remuneration from the Programs for their services to the Programs. See "Salary Reimbursement Table" below. The allocable general and administrative, geological, and engineering expenses are apportioned on a reasonable basis between the Programs' business and all other oil and natural gas activities of Dyco and its affiliates, including Dyco's management and operation of affiliated oil and gas limited partnerships. The allocation to the Programs 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 Programs for their services. However, to the extent such services represent direct involvement with the Programs, as opposed to general corporate functions, such persons' salaries are allocated to and reimbursed by the Programs. Such allocation to the Programs' general and administrative, geological, and engineering expenses of the salaries of directors, officers, and employees of Dyco and its affiliates is based on internal records maintained by Dyco and its affiliates, and represents investor relations, legal, accounting, data processing, management, and other functions directly attributable to the Programs' operations. The following table indicates the approximate amount of general and administrative expense reimbursement attributable to the salaries of the directors, officers, and employees of Dyco and its affiliates for the three years ended December 31, 1995: 51
1979-1 Program -------------- Salary Reimbursement Three Years Ended December 31, 1995 Long Term Compensation ------------------------------- Annual Compensation Awards Payouts ------------------------- --------------------- ------- Securi- Other ties All Name Annual Restricted Under- Other and Compen- Stock lying LTIP Compen- Principal Salary Bonus sation Award(s) Options/ Payouts sation Position Year ($) ($) ($) ($) SARs(#) ($) ($) - - --------------- ---- ------- ------- ------- ---------- -------- ------- ------- C. Philip Tholen, President, Chief Executive Officer 1993 - - - - - - - 1994 - - - - - - - 1995 - - - - - - - All Executive Officers, Directors, and Employees as a group 1993 $23,368 - - - - - - 1994 $24,263 - - - - - - 1995 $24,308 - - - - - - - - --------------- The general and administrative expenses paid by the 1979-1 Program and attributable to salary reimbursements do not include any salary or other compensation attributable to Mr. Tholen. No officer or director of Dyco or its affiliates provides full-time services to the 1979-1 Program and no individual's salary or other compensation reimbursement from the 1979-1 Program equals or exceeds $100,000 per annum.
52
1979-2 Program -------------- Salary Reimbursement Three Years Ended December 31, 1995 Long Term Compensation ------------------------------- Annual Compensation Awards Payouts ------------------------- --------------------- ------- Securi- Other ties All Name Annual Restricted Under- Other and Compen- Stock lying LTIP Compen- Principal Salary Bonus sation Award(s) Options/ Payouts sation Position Year ($) ($) ($) ($) SARs(#) ($) ($) - - --------------- ---- ------- ------- ------- ---------- -------- ------- ------- C. Philip Tholen, President, Chief Executive Officer 1993 - - - - - - - 1994 - - - - - - - 1995 - - - - - - - All Executive Officers, Directors, and Employees as a group 1993 $16,383 - - - - - - 1994 $17,011 - - - - - - 1995 $17,042 - - - - - - - - --------------- The general and administrative expenses paid by the 1979-2 Program and attributable to salary reimbursements do not include any salary or other compensation attributable to Mr. Tholen. No officer or director of Dyco or its affiliates provides full-time services to the 1979-2 Program and no individual's salary or other compensation reimbursement from the 1979-2 Program equals or exceeds $100,000 per annum.
53 In addition to the compensation/reimbursements noted above, during the three years ended December 31, 1995, the Samson Companies were in the business of supplying field and drilling equipment and services to affiliated and unaffiliated parties in the industry. These companies may have provided equipment and services for wells in which the Programs have an interest. Such equipment and services were provided at prices or rates equal to or less than those normally charged in the same or comparable geographic area by unaffiliated persons or companies dealing at arm's length. The operators of these wells bill the Programs for a portion of such costs based upon the Programs' 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 Programs' Units as of December 31, 1995 by each beneficial owner of more than 5% of the issued and outstanding Units and by the directors, officers, and affiliates of Dyco. The address of each of such persons is Samson Plaza, Two West Second Street, Tulsa, Oklahoma 74103. Number of Units Beneficially Owned (Percent Beneficial Owner of Outstanding) - - ---------------------------------------------- --------------- 1979-1 Program: - - -------------- Samson Properties Incorporated 1,135.63 (35.8%) All directors, officers, and affiliates of Dyco as a group and Dyco (8 persons) 1,135.63 (35.8%) 1979-2 Program: - - -------------- Samson Properties Incorporated 1,117.98 (38.7%) All directors, officers, and affiliates of Dyco as a group and Dyco (8 persons) 1,117.98 (38.7%) To the best knowledge of the Programs and Dyco, there were no officers, directors, or 5% owners who were delinquent filers of 54 reports required under section 16 of the Securities Exchange Act of 1934. ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS Dyco and certain of its affiliates engage in oil and gas activities independently of the Programs 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 Programs and Dyco also create potential conflicts of interest. Dyco and its affiliates own a significant amount of the Programs' Units and therefore have an identity of interest with other limited partners with respect to the operations of the Programs. In order to attempt to assure limited liability for limited partners as well as an orderly conduct of business, management of the Programs is exercised solely by Dyco. The partnership agreements of the Programs grant Dyco broad discretionary authority with respect to the Programs' participation in drilling prospects and expenditure and control of funds, including borrowings. These provisions are similar to those contained in prospectuses and partnership agreements for other public oil and gas partnerships. Broad discretion as to general management of the Programs involves circumstances where Dyco has conflicts of interest and where it must allocate costs and expenses, or opportunities, among the Programs and other competing interests. Dyco does not devote all of its time, efforts, and personnel exclusively to the Programs. Furthermore, the Programs do not have any employees, but instead rely on the personnel of the Samson Companies. The Programs thus compete with the Samson Companies (including other currently sponsored oil and gas programs) for the time and resources of such personnel. The Samson Companies devote such time and personnel to the management of the Programs as are indicated by the circumstances and as are consistent with Dyco's fiduciary duties. Affiliates of the Programs are solely responsible for the negotiation, administration, and enforcement of oil and gas sales agreements covering the Programs' leasehold interests. Until December 6, 1995, Dyco had delegated the negotiation, administration, and enforcement of its oil and gas sales agreements to Premier. In addition to providing such administrative services, Premier purchased and resold gas directly to end-users and local distribution companies. Because affiliates of the Programs who provide services to the Programs have fiduciary or other duties to other members of the Samson Companies, contract amendments and negotiating positions taken by them in their effort to enforce contracts with purchasers may not necessarily represent the positions that a Program would take if it were to administer its own contracts without involvement with other 55 members of the Samson Companies. On the other hand, management believes that the Programs' negotiating strength and contractual positions have been enhanced by virtue of its affiliation with the Samson Companies. For a description of certain other relationships and related transactions see "Item 11. Executive Compensation." PART IV ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K (a) Financial Statements and Schedules. The following financial statements and schedules for the Programs as of December 31, 1995 and 1994 and for the years ended December 31, 1995, 1994, and 1993 are filed as part of this report. (1) Financial Statements: Reports of Independent Accountants Balance Sheets Statements of Operations Statements of Partners' Capital Statements of Cash Flows Notes to Financial Statements (2) Financial Statement Schedules: None All other schedules have been omitted since the required information is presented in the Financial Statements or is not applicable. (b) Reports on Form 8-K for the fourth quarter of 1995: None. (c) Exhibits: 4.1 Drilling Agreement dated April 2, 1979 for Dyco Drilling Program 1979-1 by and between Dyco Oil and Gas Program 1979-1, Dyco Petroleum Cor- poration, 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 herein. 56 4.2 Form of Program Agreement for Dyco Oil and Gas Program 1979-1 by and between Dyco Petroleum Corporation and the 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 herein. 4.3 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-1 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 herein. 4.4 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-1 Limited Partnership filed as Exhibit 4.4 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.5 Drilling Agreement dated July 2, 1979 for Dyco Drilling Program 1979-2 by and between Dyco Oil and Gas Program 1979-2, Dyco Petroleum Corporation, and Jaye F. Dyer filed as Exhibit 4.5 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.6 Form of Program Agreement for Dyco Oil and Gas Program 1979-2 by and between Dyco Petroleum Corporation and the Participants filed as Exhibit 4.6 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.7 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-2 dated February 9, 1989 filed as Exhibit 4.7 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.8 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-2 Limited Partnership filed as Exhibit 4.8 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 27.1 Financial Data Schedule containing summary financial information extracted from the Dyco 57 Oil and Gas Program 1979-1 Limited Partnership's financial statements as of December 31, 1995 and for the year ended December 31, 1995. 27.2 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-2 Limited Partnership's financial statements as of December 31, 1995 and for the year ended December 31, 1995. All other Exhibits are omitted as inapplicable. 58 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 1979-1 LIMITED PARTNERSHIP By: DYCO PETROLEUM CORPORATION General Partner February 14, 1996 By: /s/C. Philip Tholen ------------------------------ C. Philip Tholen Chief Executive Officer and President Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities on the dates indicated. By: /s/C. Philip Tholen Chief Executive Feb. 14, 1996 ------------------- Officer, President, C. Philip Tholen and Chairman of the Board (Principal Executive Officer) /s/Dennis R. Neill Senior Vice Feb. 14, 1996 ------------------- President and Dennis R. Neill Director /s/Jack A. Canon Senior Vice Feb. 14, 1996 ------------------- President - Jack A. Canon General Counsel and Director /s/Patrick M. Hall Senior Vice Feb. 14, 1996 ------------------- President - Patrick M. Hall Controller (Principal Accounting Officer) /s/Annabel M. Jones Secretary Feb. 14, 1996 ------------------- Annabel M. Jones /s/Judy F. Hughes Treasurer Feb. 14, 1996 ------------------- Judy F. Hughes 59 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 1979-2 LIMITED PARTNERSHIP By: DYCO PETROLEUM CORPORATION General Partner February 14, 1996 By: /s/C. Philip Tholen ------------------------------ C. Philip Tholen Chief Executive Officer and President Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities on the dates indicated. By: /s/C. Philip Tholen Chief Executive Feb. 14, 1996 ------------------- Officer, President, C. Philip Tholen and Chairman of the Board (Principal Executive Officer) /s/Dennis R. Neill Senior Vice Feb. 14, 1996 ------------------- President and Dennis R. Neill Director /s/Jack A. Canon Senior Vice Feb. 14, 1996 ------------------- President - Jack A. Canon General Counsel and Director /s/Patrick M. Hall Senior Vice Feb. 14, 1996 ------------------- President - Patrick M. Hall Controller (Principal Accounting Officer) /s/Annabel M. Jones Secretary Feb. 14, 1996 ------------------- Annabel M. Jones /s/Judy F. Hughes Treasurer Feb. 14, 1996 ------------------- Judy F. Hughes 60 INDEX TO EXHIBITS Exhibit Number Description - - ------- ----------- 4.1 Drilling Agreement dated April 2, 1979 for Dyco Drilling Program 1979-1 by and between Dyco Oil and Gas Program 1979- 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 herein. 4.2 Form of Program Agreement for Dyco Oil and Gas Program 1979- 1 by and between Dyco Petroleum Corporation and the 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 herein. 4.3 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-1 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 herein. 4.4 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-1 Limited Partnership filed as Exhibit 4.4 to Annual Report on Form 10-K for the year ended Decem- ber 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.5 Drilling Agreement dated July 2, 1979 for Dyco Drilling Pro- gram 1979-2 by and between Dyco Oil and Gas Program 1979-2, Dyco Petroleum Corporation, and Jaye F. Dyer filed as Exhibit 4.5 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.6 Form of Program Agreement for Dyco Oil and Gas Program 1979- 2 by and between Dyco Petroleum Corporation and the Participants filed as Exhibit 4.6 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 4.7 Amendment to Program Agreement for Dyco Oil and Gas Program 1979-2 dated February 9, 1989 filed as Exhibit 4.7 to Annual Report on Form 10-K for the year ended December 31, 1991 on April 10, 1992 and is hereby incorporated herein. 61 4.8 Certificate of Limited Partnership (as amended) for Dyco Oil and Gas Program 1979-2 Limited Partnership filed as Exhibit 4.8 to Annual Report on Form 10-K for the year ended Decem- ber 31, 1991 on April 10, 1992 and is hereby incorporated herein. 27.1 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-1 Limited Partnership's financial statements as of December 31, 1995 and for the year ended December 31, 1995. 27.2 Financial Data Schedule containing summary financial information extracted from the Dyco Oil and Gas Program 1979-2 Limited Partnership's financial statements as of December 31, 1995 and for the year ended December 31, 1995. 62 EX-27 2
5 0000806573 DYCO OIL AND GAS PROGRAM 1979-1 LIMITED PARTNERSHIP 12-MOS DEC-31-1995 JAN-01-1995 DEC-31-1995 32,509 0 74,181 0 0 106,690 20,452,284 20,160,567 467,816 20,125 0 0 0 0 409,567 467,816 396,493 398,559 0 226,939 0 0 0 171,620 0 171,620 0 0 0 171,620 54.00 0
EX-27 3
5 0000806574 DYCO OIL AND GAS PROGRAM 1979-2 LIMITED PARTNERSHIP 12-MOS DEC-31-1995 JAN-01-1995 DEC-31-1995 105,766 0 91,623 0 0 197,389 18,562,544 18,122,183 705,367 42,776 0 0 0 0 662,591 705,367 483,467 490,205 0 229,114 0 0 0 261,091 0 261,091 0 0 0 261,091 90.00 0
-----END PRIVACY-ENHANCED MESSAGE-----