ITEM 1. BUSINESS
Sterling Drilling Fund 1984-1, L.P., formerly Sterling-Fuel Resources Drilling Fund 1984-1 (the "Registrant" or the "Partnership") is a limited partnership formed under the laws of the State of New York on June 26, 1984. The sole business of the Partnership was the drilling of formation extension wells principally for natural gas in various locations in the State of West Virginia. No exploratory drilling was undertaken.
The principal place of business of the Partnership is at One Landmark Square, Stamford, Connecticut 06901, telephone (203) 358-5700. The Managing General Partner of the Partnership is PrimeEnergy Management Corporation, a New York corporation, which is a wholly-owned subsidiary of PrimeEnergy Corporation, a publicly held Delaware corporation. Messrs. Charles E. Drimal, Jr., Oliver J. Sterling and Samuel R. Campbell also are General Partners. Mr. Drimal is a Director, President and Chief Executive Officer of PrimeEnergy Management Corporation and PrimeEnergy Corporation, and Mr. Campbell is a Director of PrimeEnergy Corporation.
The aggregate contributions to the Partnership were $9,236,000 all of which, net of the organization expenses of the Partnership, was expended in the drilling of such formation extension wells. Such properties are located in Clay, Roane, Calhoun, Boone, Wirt, Kanawha, Lincoln and Putnam Counties, West Virginia and various counties in eastern Kentucky. The Partnership does not operate any of the properties in which it has an interest, but generally such properties are operated and serviced by Prime Operating Company, a Texas corporation, and Eastern Oil Well Service Company, a West Virginia corporation, both wholly-owned subsidiaries of PrimeEnergy Corporation.
During 1996, the Partnership did not engage in any development drilling activities or the acquisition of any significant additional properties, but engaged in the production of oil and gas from its producing properties in the usual and customary course. Since January 1, 1997, and to the date of this Report, the Partnership has not engaged in any drilling activities nor participated in the acquisition of any material producing oil and gas properties.
COMPETITION AND MARKETS
Competitors of the Partnership in the marketing of its oil and gas production include oil and gas companies, independent concerns, and individual producers and operators, many of which have financial resources, staffs and facilities substantially greater than those available to the Partnership. Furthermore, domestic producers of oil and gas must not only compete with
each other in marketing their output, but must also compete with producers of imported oil and gas and alternative energy sources such as coal, nuclear power and hydro-electric power.
The availability of a ready market for any oil and gas produced by the Partnership at acceptable prices per unit of production will depend upon numerous factors beyond the control of the Partnership, including the extent of domestic production and importation of oil and gas, the proximity of the Partnership's producing properties to gas pipelines and the availability and capacity of such pipelines, the marketing of other competitive fuels, fluctuation in demand, governmental regulation of production, refining, transportation and sales, general national and worldwide economic conditions, and pricing, use and allocation of oil and gas and their substitute fuels.
The Partnership does not currently own or lease any bulk storage facilities or pipelines, other than adjacent to and used in connection with producing wells. The Partnership deals with a number of major and independent companies for the purchase of its oil and gas production, in the areas of production. In 1995, about $201,000, or 99%, of the Partnership's gas production was sold to Phoenix Diversified and about $40,000 or 100%, of the Partnership's oil production was sold to American Rivers Terminals. Neither purchaser has any relationship or is otherwise affiliated with the Partnership. The Partnership believes that its current purchasers will continue to purchase oil and gas products and, if not, could be replaced by other purchasers.
ENVIRONMENTAL MATTERS
The petroleum industry is subject to numerous federal and state environmental statutes, regulations and other pollution controls. In general, the Partnership is, and will be subject to, present and future environmental statutes and regulations, and in the future the cost of its activities may materially increase as a result thereof. The Partnership's expenses relating to preserving the environment during 1996 as they relate to its oil and gas operations were not significant in relation to operating costs and the Partnership expects no material change in the near future. The Partnership believes that environmental regulations should not, in the future, result in a curtailment of production or otherwise have a materially adverse effect on the Partnership's operations or financial condition.
REGULATION
The Partnership's oil and gas operations are subject to a wide variety of federal, state and local regulations. Administrative agencies in such jurisdictions may promulgate and enforce rules and regulations relating to, among other things, drilling and spacing of oil and gas wells, production rates, prevention of waste, conservation of natural gas and oil, pollution control, and various other matters, all of which may affect the Partnership's future operations and production of oil and gas. The Partnership's natural gas production and prices received for natural gas are regulated by the Federal Energy Regulatory Commission and the Natural Gas Policy Act of 1978 and various state regulations. The Partnership was subject to the Crude Oil Windfall Profit Tax Act of 1980, which imposed an excise tax on producers of crude oil at various rates for prices received in excess of certain historical base prices. That Act was repealed in August, 1988. The Partnership is also subject to state drilling and proration regulations affecting its drilling operations and production rates.
The FERC continues to regulate interstate natural gas pipeline transportation rates and service conditions pursuant to the NGA and NGPA. Federal regulation of interstate transporters affects the marketing of natural gas produced by the Partnership as well as the revenues received by the Partnership for sales of such natural gas. Since the latter part of 1985, through its Order Nos. 436, 500 and 636 rulemakings, the FERC has endeavored to make natural gas transportation accessible to gas buyers and sellers on an open and non-discriminatory basis. The FERC's efforts have significantly altered the marketing and pricing of natural gas. No prediction can be made as to what additional legislation may be proposed, if any, affecting the competitive status of a gas producer, restricting the prices at which a producer may sell its gas, or the market demand for gas, nor can it be predicted which proposals, including those presently under consideration, if enacted, might be effective.
A number of legislative proposals have been introduced in Congress and the state legislatures of various states, that, if enacted, would significantly affect the petroleum industry. Such proposals involve, among other things, the imposition of land and use controls and certain measures designed to prevent petroleum companies from acquiring assets in other energy areas. In addition, there is always the possibility that if market conditions change dramatically in favor of oil and gas producers that some new form of "windfall profit" or severance tax may be proposed for and imposed upon either oil or gas. At the present time it is impossible to predict which proposals, if any, will actually be enacted by Congress or the various state legislatures. The Partnership believes that it will comply with all orders and regulations applicable to its operations. However, in view of the many uncertainties with respect to the current controls, including their duration and possible modification together with any new proposals that may be enacted, the Partnership cannot predict the overall effect, if any, of such controls on its operations.
TAXATION
The Partnership received an opinion of its counsel that the Partnership would be classified as a partnership and the holders of Partnership Units would be treated as limited partners for federal income tax purposes. The Partnership itself, to the extent that it is treated for federal income tax purposes as a partnership, is not subject to any federal income taxation, but it is required to file annual partnership returns. Each holder of Partnership Units will be allocated his distributive shares of the Partnership's income, gain, profit, loss, deductions, credits, tax preference items and distributions for any taxable year of the Partnership ending within or with his taxable year without regard as to whether such holder has received or will receive any cash distributions from the Partnership.
ITEM 2.

ITEM 2. PROPERTIES
The Partnership has no interest in any properties other than its oil and gas properties. The information set forth below summarizes the Partnership's oil and gas wells, production and reserves, for the periods indicated.
PRODUCING WELLS AND OPERATING INFORMATION
The Partnership, following its formation, and in October, 1984, contracted for the drilling of 32 development wells, which resulted in 32 producing wells.
As of December 31, 1996, the Partnership had ownership interests in the following gross and net producing oil and gas wells and gross and net producing acres.(1) The Partnership has no material undeveloped leasehold, mineral or royalty acreage.
Producing wells:
- --------------------------- (1) A gross well is a well in which an interest is owned; a net well is the sum of the interests owned in gross wells. Wells are classified by their primary product. Some wells produce both oil and gas.
The following table sets forth the Partnership's oil and gas production, average sales prices and average production costs as of and for the periods indicated:
OIL AND GAS RESERVES
The Partnership's interests in proved developed oil and gas properties have been evaluated by Ryder Scott Company for the periods indicated below. All of the Partnership's reserves are located in the continental United States. The following table summarizes the Partnership's oil and gas reserves at the dates shown (figures rounded):
The estimated future net revenue (using current prices and costs as of the dates indicated, exclusive of income taxes (at a 10% discount for estimated timing of cash flow) for the Partnership's proved developed oil and gas reserves for the periods indicated are summarized as follows (figures rounded):
Since January 1, 1996, the Partnership has not filed any estimates of its oil and gas reserves with, nor were any such estimates included in any reports, to any federal authority or agency, other than the Securities and Exchange Commission.
ITEM 3.

ITEM 3. LEGAL PROCEEDINGS
The Partnership is not a party to, nor is any of its property the subject of, any legal proceedings actual or threatened, which would have a material adverse effect on the business and affairs of the Partnership.
ITEM 4.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no matters submitted during 1996 for vote by the holders of Partnership Units.
PART II
ITEM 5.

ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
There is no market for the Limited Partnership Units (the "Units") of the Partnership. As of March 14, 1997, there were 711 holders of record of the Units.
The Units are not regarded as stock and payments or distributions to holders of the Units are not made in the form of dividends. Cash distributions to the holders of Units for 1996 aggregated $23,090. Aggregate cash distributions to the holders of the Units as of December 31, 1996, is $1,662,480.
The Managing General Partner may purchase Units directly from the unit holders if presented to the Managing General Partner, subject to conditions, including limitations on numbers of Units, and at a price to be fixed by the Managing General Partner in accordance with certain procedures, all as provided for in the Limited Partnership Agreement of the Partnership.
ITEM 6.

ITEM 6. SELECTED FINANCIAL DATA
The following table summarizes certain selected financial data to highlight significant trends in the Registrant's financial condition and results of operations for the periods indicated. The selected financial data should be read in conjunction with the financial statements and related notes included elsewhere in this report.
ITEM 7.

ITEM 7. MANAGEMENT'S DISCUSSION & ANALYSIS OF FINANCIAL CONDITION & RESULTS OF OPERATIONS
1. Liquidity: The oil and gas industry is intensely competitive in all its phases. There is also competition between this industry and other industries in supplying energy and fuel requirements of industrial and residential consumers. It is not possible for the Registrant to calculate its position in the industry as the Registrant competes with many other companies having substantially greater financial and other resources. In accordance with the terms of the Agreement of Limited Partnership of the Partnership, the General Partners of the Registrant will make cash distributions of as much of the partnership cash credited to the capital accounts of the partners as the General Partners have determined is not necessary or desirable for the payment of any contingent debts, liabilities or expenses for the conduct of the Partnership business. As of December 31, 1996, the General Partners have distributed $1,662,480 or 18.0% of original Limited Partner capital contributions, to the Limited Partners.
The net proved oil and gas reserves of the Partnership are considered to be a primary indicator of financial strength and future liquidity. The present value of unescalated future net revenues (S.E.C. case) associated with such reserves, discounted at 10% as of December 31, 1996, was approximately $986,600, as compared to $689,000 as of December 31, 1995. The increase in total estimated discounted future net revenue was due in part to higher year end gas prices as of December 31, 1996, when compared to the low gas price in effect as of December 31, 1995. Overall reservoir engineering is a subjective process of estimating underground accumulations of gas and oil that can not be measured in an exact manner. The accuracy of any reserve estimate is a function of the quality of available data and of the engineering and geological interpretation and judgment. Accordingly, reserve estimates are generally different
from the quantities of gas and oil that are ultimately recovered and such differences may have a material impact on the partnership's financial results and future liquidity.
2. Capital Resources: The Partnership was formed for the sole intention of drilling oil and gas wells. The Partnership entered into a drilling contract with an independent contractor in October, 1984, for $7,750,000. Pursuant to the terms of this contract, thirty-two wells were drilled resulting in thirty-two producing wells.
3. Results of operations:
1996 compared to 1995
Operating revenue showed a minor increase from $242,920 in 1995 to $245,496 in 1996. This increase can be attributed to a production increase, from 83,970 mcfs in 1995 to 85,614 mcfs in 1996, combined with a relatively unchanged average gas price per mcf, $2.36 in 1995 and $2.38 in 1996. The Partnership generally renews its contracts with gas purchasers as they come due for an additional twelve month period. The Partnership was able to obtain fixed price contracts on a significant amount of its gas production for 1996. The Partnership also successfully renewed its contracts for 1997.
Interest income fluctuates with changes in the interest rates received as well as the amount of cash in the bank at any given time.
Production expenses decreased from $123,898 in 1995 to $121,844 in 1996. Most of the production expenses incurred in 1995 and 1996 were to maintain the general upkeep of the wells and well sites. The Partnership did expend funds on additional capitalized well equipment. The operator will determine if additional equipment, for example lift equipment, will have a favorable effect on production. The beneficial effect looked for by the operator is to increase, improve or sustain production on a particular well. General and administrative costs remained substantially unchanged, from $81,141 in 1995 to $80,802 in 1996. Management continues to monitor any third party costs and use in-house resources if it will provide efficient and timely services to the Partnership. The lower amounts reflect management's efforts to limit cots, both incurred and allocated to the Partnership. Amounts in both years are substantially less then the $461,800 allocable to the Partnership under the Partnership Agreement.
The Partnership records additional depreciation, depletion and amortization to the extent that the net capitalized costs exceeds the undiscounted future net cash flows attributable to the Partnership. No additional revision was needed in 1996 or 1995. The overall Partnership depreciation was consistent with the current basis in the Partnership properties and the rates applied.
1995 compared to 1994
Operating revenue declined from $282,404 in 1994 to $242,920 in 1995. This decline can be attributed to a production increase from 75,776 mcfs in 1994 to 83,970 mcfs in 1995, combined with an average price per mcf decrease from $3.14 in 1994 to $2.38 in 1995.
The Partnership was paid spot prices throughout all of 1995 for its gas produced. Spot prices fluctuate and were low during off peak usage times of the year. The Partnership generally renews contracts as they come due for an additional twelve month period. The Partnership was under a fixed contract price for the first nine months of 1994. The price offered in 1994 at the renewal date for the 1994-1995 contracts, was lower than was deemed favorable. Therefore, the price remained at spot prices during 1994 and 1995. During the fourth quarter of 1995, the Partnership locked into a twelve month fixed price contract.
Columbia Gas Transmission Corp., a gas purchaser of the Partnership's gas, filed a Chapter 11 petition in the U.S. Bankruptcy Court in Wilmington, Delaware, on July 31, 1991. At that time, the Bankruptcy Court released Columbia from any active contracts. The Partnership filed a claim with the Bankruptcy Court to recover revenues suspended at the time the bankruptcy occurred. Such amounts were not recorded during the applicable period since the claim amount was undetermined and open-ended. The Court's settlement of the Columbia bankruptcy proceedings were finalized in November of 1995. The Partnership received $73,129, which was reported as other income for 1995.
Interest income fluctuates with changes in the interest rates received as well as the amount of cash in the bank at any given time.
Production expenses decreased from $155,414 in 1994 to $123,898 in 1995. The higher production expenses in 1994 were attributed to higher labor, repairs and location costs associated with the inclement weather conditions throughout 1994. The weather caused line damages, floods and other situations that increased normal maintenance costs. General and administrative costs showed a substantial decrease from $130,339 in 1994 to $81,141 in 1995. Amounts in both years are substantially less than the $461,800 allocable to the Partnership under the Partnership Agreement. The lower amounts reflect management's efforts to limit costs, both incurred and allocated to the Partnership. Management continues to monitor any third party costs and use in-house resources if it will provide efficient and timely services to the Partnership.
The Partnership records additional depreciation, depletion and amortization to the extent that the net capitalized costs exceeds the undiscounted future net cash flows attributable to the Partnership. The Partnership recorded a downward revision of $450,000 in 1994. No additional revision was needed in 1995. Depreciation, depletion and amortization rates as well as the Partnership's basis in its properties were significantly lower in 1995 compared to 1994. Therefore, the Partnership's depreciation, depletion and amortization expense was lower in 1995 than in 1994, $48,661 and $104,898 respectively.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Partners of Sterling Drilling Fund 1984-1, L.P.:
We have audited the accompanying balance sheets of Sterling Drilling Fund 1984-1, L.P. (a New York limited partnership) as of December 31, 1996 and 1995, and the related statements of operations, changes in partners' equity, and cash flows for the years ended December 31, 1996, 1995 and 1994. These financial statements are the responsibility of the Partnership's management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Sterling Drilling Fund 1984-1, L.P. as of December 31, 1996 and 1995, and the results of its operations and cash flows for the years ended December 31, 1996, 1995 and 1994 in conformity with generally accepted accounting principles.
Our audits were made for the purpose of forming an opinion on the basic financial statements taken as a whole. The schedules listed in the index to financial statements and schedules are presented for purposes of complying with the Securities and Exchange Commission's rules and are not part of the basic financial statements. These schedules have been subjected to the auditing procedures applied in the examination of the basic financial statements and, in our opinion, fairly state in all material respects the financial data required to be set forth therein in relation to the basic financial statements taken as a whole.
PUSTORINO, PUGLISI & CO., LLP New York, New York January 31, 1997
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
BALANCE SHEETS
DECEMBER 31, 1996 AND 1995
Assets ------
The Notes to Financial Statements are an integral part of these statements.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED DECEMBER 31, 1996, 1995 AND 1994
The Notes to Financial Statements are an integral part of these statements.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
STATEMENTS OF CHANGES IN PARTNERS' EQUITY
FOR THE YEARS ENDED DECEMBER 31, 1996, 1995 AND 1994
The Notes to Financial Statements are an integral part of these statements.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 1996, 1995 AND 1994
The Notes to Financial Statements are an integral part of these statements.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(1) Organization and Capital Contributions:
Sterling Drilling Fund 1984-1, L.P., was formed on June 26, 1984, in the state of West Virginia, for the primary purpose of acquiring, developing and producing oil and gas in the state of West Virginia. The general partners are: PrimeEnergy Management Corporation (PEMC), a wholly owned subsidiary of PrimeEnergy Corporation (PEC), Charles E. Drimal, Jr., Oliver J. Sterling and Samuel R. Campbell. Nine thousand two hundred thirty-six limited partnership units, (9,236), were sold at $1,000 per unit aggregating total limited partner contributions of $9,236,000. The general partners' contributions amounted to $506,656. Partnership operations commenced on October 19, 1984.
(2) Summary of Significant Accounting Policies:
Revenue Recognition:
The Partnership recognizes operating revenues, consisting of sales of oil and gas production, in the month of sale. Uncollected revenue is accrued based on known facts and trends of the relevant oil and gas properties on a monthly basis.
Basis of Accounting:
The accounts of the Partnership are maintained in accordance with accounting practices permitted for federal income tax reporting purposes. Under this method of accounting, (a) substantially all exploration and development costs except leasehold and equipment costs are expensed as paid, (b) costs of abandoned leases and equipment are expensed when abandoned, and (c) depreciation (for equipment placed in service) is provided on an accelerated basis. In order to present the accompanying financial statements in accordance with generally accepted accounting principles, memorandum adjustments have been made to account for oil and gas properties, as discussed below.
Oil and Gas Producing Activities:
The Partnership accounts for its oil and gas operations using the successful efforts method of accounting on a property by property basis. The Partnership only participates in developmental drilling. Accordingly, all costs of drilling and equipping these wells, together with leasehold acquisition costs, are capitalized. These capitalized costs are amortized on a property by property basis by the unit-of-production method based upon the ratio of production to proved oil and gas reserves. Additional depreciation, depletion and amortization is recorded to the extent that net capitalized costs exceed the undiscounted future net cash flows attributable to Partnership properties. (See Note 4)
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(2) Summary of Significant Accounting Policies - (Cont'd):
Federal Income Taxes:
As federal income taxes are the liability of the individual partners, the accompanying financial statements do not include any provision for federal income taxes. (See Note 8)
Limited Partners' Loss Per Equity Unit:
The limited partners' loss per equity unit is computed on the 9,236 limited partner equity units.
Cash and Cash Equivalents:
For purposes of the statements of cash flows the Partnership considers all highly liquid debt instruments with a maturity of three months or less to be cash equivalents.
Use of Estimates:
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.
Recently Issued Accounting Standards:
The Partnership has implemented the provisions of FAS Statement No. 121 "Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed of." The implementation of this standard has had no material effect on the financial statements.
(3) Oil and Gas Properties:
The Partnership acquired leases or farmouts from PEMC at its cost. Cost is defined as any amount paid for delay rentals, lease bonuses, if any, surveys and other expenses including such portion of any of the general partners', or their affiliates' reasonable, necessary and actual expenses for geological, geophysical, seismic, land, engineering, drafting, accounting, legal and other services. The Partnership currently pays royalties of approximately 12.5% to 18.4% of the selling price of the oil and gas extracted.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(3) Oil and Gas Properties - (Cont'd):
The following table sets forth certain revenue and expense data concerning the Partnership's oil and gas activities for the years ended December 31, 1996, 1995 and 1994:
(4) Quantities of Oil and Gas Reserves:
The amount of proved reserves presented below has been estimated by an independent firm of petroleum engineers as of January 1, 1997. Petroleum engineers on the staff of PEC have reviewed the data presented below, as of December 31, 1996, for consistency with current year production and operating history. All of the Partnership's oil and gas reserves are located within the United States.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(4) Quantities of Oil and Gas Reserves - (Cont'd):
Should current prices continue into the future, operation of certain wells would become uneconomic, on a pretax basis, as production levels decline with age. In accordance with the rules and regulations of the Securities and Exchange Commission, proved reserves exclude production which would be uneconomic. The partners are entitled to certain tax benefits and credits which, if available in the future, may result in production continuing beyond the level included in the above table.
Revisions arise from changes in current prices , as well as, engineering and geological data which would alter the useful life and therefore the overall predicted production of each well. Future changes in these estimates are common and would impact the reserve quantities used to calculate depreciation, depletion, and amortization.
As discussed in Note 2, the Partnership records additional depreciation, depletion and amortization to the extent that net capitalized costs exceed the undiscounted future net cash flows attributable to Partnership properties. Significant price declines affect estimated future net revenues both directly and as a consequence of their impact on estimates of future production. The Partnership has recorded no additional provision of 1996 and 1995, however, an additional provision of $450,000 was recorded for 1994. If the additional provision had been computed based on the limited partners' interest in capitalized costs and estimated future net revenues, rather than on the basis of total Partnership interests, the limited partners income for the year ended December 31, 1996 and 1995 would not have been reduced , however, for the year ended December 31, 1994 it would have been reduced by an additional $125,000.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(5) Allocation of Partnership Revenues, Costs and Expenses:
Under the terms of the Limited Partnership Agreement, all Partnership revenues and expenses, including deductions attributable thereto, are to be allocated as follows:
(6) Transactions With Affiliates:
(a) The due from affiliates at December 1996 and 1995, represents net revenue collected by and costs incurred on behalf of the Partnership by PEC or its subsidiaries.
(b) As operator of the Partnership's properties, Prime Operating Company (POC), a subsidiary of PEC, receives, as compensation from the Partnership, a monthly production operator's fee of $380 for each producing gas well and $530 for each producing or combination gas and oil well, based on the Partnership's percentage of working interest in the well. Such fee is subject to annual adjustment by the percentage increase in the Consumer Price Index published by the U.S. Department of Labor over the year in which production began. During 1996, 1995 and 1994, $75,062, $64,538, and $85,154 of production operators fees were incurred respectively.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(6) Transactions With Affiliates - (Cont'd):
(c) In accordance with the terms of the Partnership Agreement, the general partners are required to pay 8.5% of drilling and completion costs, lease acquisition costs and certain other costs, of which 1% will be paid for by the general partners out of revenues received by them from the Partnership. At December 31, 1996, $33,313 was due from certain general partners for such costs.
(d) Eastern Oil Well Services Company (EOWSC), a subsidiary of PEC, provided field services to the Partnership during the year ending December 31, 1996 for which it was billed $4,191.
(7) General and Administrative Expenses:
In accordance with the Management Agreement, the general partners will be reimbursed for the portion of their in-house overhead, including salaries and related benefits, attributable to the affairs and operations of the Partnership.
This amount, combined with certain direct expenses for geology, engineering, legal, accounting, auditing, insurance and other items shall not exceed an annual amount equal to 5% of limited partner capital contributions. Excess expenses shall be borne by the general partners in their individual capacity.
During 1996, 1995 and 1994, the Partnership recognized general and administrative expenses incurred on its behalf by a general partner of $60,000, $60,000 and $110,800.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(8) Federal Income Taxes:
The following is a reconciliation between the net income (loss) as reported on the Partnership's federal income tax return and the net income (loss) reported in the accompanying financial statements:
The tax returns of the Partnership, the qualifications of the Partnership as such for tax purposes, and the amount of Partnership income or loss are subject to examination by federal and state taxing authorities. If such examinations result in changes with respect to Partnership's qualifications or in changes to its income or loss, the tax liability of the partners would be changed accordingly.
The Tax Reform Act of 1976 provides that no part of any depletion deduction with respect to oil and gas wells is to be determined by the Partnership but must be computed separately by the partners. Thus, cost or percentage depletion, as applicable, must be computed by each partner so that a specific depletion computation can be made when each partner files his U.S. income tax return. Information is furnished to the partners to compute the depletion deduction.
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 1996, 1995 AND 1994
(9) Major Customers:
A schedule of the major purchases of the Partnership's production is as follows:
The Partnership renewed its gas purchase contract in December, 1996 resulting in a fixed price for one year.
(10) Other Revenue:
Other revenue represents settled claims against Columbia Gas Transmission Corp. (Columbia) arising from amounts due from Columbia when they declared bankruptcy. No significant additional claims are expected concerning this matter.
SCHEDULE V
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
PROPERTY AND EQUIPMENT - OIL AND GAS PROPERTIES
FOR THE YEARS ENDED DECEMBER 31, 1996, 1995 AND 1994
SCHEDULE VI
STERLING DRILLING FUND 1984-1, L.P. (a New York limited partnership)
ACCUMULATED DEPRECIATION, DEPLETION AND AMORTIZATION - OIL AND GAS PROPERTIES
FOR THE YEARS ENDED DECEMBER 31, 1996, 1995 AND 1994
INDEX TO EXHIBITS