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SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the Quarterly Period Ended September 30, 2002

or

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

For the Transition Period Ended _____________________________

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 too such filing requirements for the past 90 days. Yes/X/ No / /

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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations

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 Registrant competes with many other companies having substantially greater financial and other resources. In accordance with the terms of the Prospectus as filed by the Registrant, 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 contingent debts, liabilities or expenses for the conduct of the Partnership's business. As of September 30, 2002, the General Partners have distributed $2,630,787.50 or 23.75% 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. Reservoir engineering is a subjective process of estimating underground accumulations of gas and oil that cannot be measured in an exact manner. The estimated reserve quantities and future income quantities are related to hydrocarbon prices. Therefore, volumes of reserves actually recovered and amounts of income actually received may differ significantly from the estimated quantities presented in this report.

In accordance with FASB Statement No. 69, December 31, 2001 market prices were determined using the daily oil price or daily gas sales price ("spot price") adjusted for oilfield or gas gathering hub and wellhead price differentials (e.g. grade, transportation, gravity, sulfur, and BS&W) as appropriate. Also, in accordance with SEC and FASB specifications, changes in market prices subsequent to December 31, 2000 and 2001 were

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not considered. The spot price for gas at December 31, 2000 was $9.23 per MMBTU. The range of spot prices during the year 2000 was a low of $2.14 and a high of $10.50 and the average was $4.28. The spot price for gas at December 31, 2001 was $2.63 per MMBTU. The range of spot prices during the year 2001 was a low of $1.77 and a high of $10.29 and the average was $3.94. . The range during the first nine months of 2002 has been from $1.98 to $4.10 with an average of $3.18. The recent futures market prices have been in the $3.94 range. The Partnership actually received an average price for gas sold of $3.54 during the first nine months of 2002.

The present value of unescalated future net revenue (S.E.C. case) associated with such reserves, discounted at 10% as of December 31, 2001, was approximately $1,140,108 as compared to the discounted reserves as of December 31, 2000, which were approximately $5,503,164. While it may reasonably be anticipated that the prices received by Sterling Drilling Fund 1983-1 for the sale of its production may be higher or lower than the prices used in this evaluation, as described above, and the operating costs relating to such production may also increase or decrease from existing levels, such possible changes in prices and costs were, in accordance with rules adopted by the SEC, omitted from consideration in making this evaluation for the SEC case. Actual volumes produced, prices received and costs incurred by the Partnership may vary significantly from the SEC case

2. Capital Resources:

The Registrant was formed for the sole intention of drilling oil and gas wells. The Registrant entered into a drilling contract with an independent contractor in November 1983 for $9,400,000. Pursuant to terms of this contract thirty-eight wells have been drilled resulting in thirty-seven producing wells and one dry hole.

During 2002, PrimeEnergy Management negotiated a Farmout Agreement with Ardent Resources Inc. covering leasehold interests in acres located in Calhoun County, West Virginia. Pursuant to this agreement, Ardent has the right but not the obligation to select acreage and drill a deep well on the selected acreage, subject to an overriding royalty interest due to the leasehold owners. If a test well is not spudded by February 13, 2005 this agreement terminates. Acreage held by Sterling Drilling Fund 1983-1 was included in the Farmout Agreement, PrimeEnergy Management may discuss the possibility of farming out additional deep rights held by the Partnership under the same terms with other parties, however, there is no guarantee that any agreement will be entered into.

3. Results of Operations -

The combination of both decreased pricing and production resulted in the Partnership's operating revenues significant increase from $451,512 in 2001 to $256,827 in 2002. The gas and oil production declined, from 77,781 MCF and 413 BBLS to 68,673 MCF and 686 BBLS in 2002. The production volume variations can be a result of changes in transportation line pressures, miscellaneous shut-ins for maintance and natural declines.

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The most significant impact to revenue was the average price per MCF decreased, from $5.68 in 2001 to $3.84 in 2002. The General Partners elected to sell a substantial portion of the gas delivered under this contract from June 2002 through October 2002 at a fixed price of $3.57 per MMBTU subject to transportation costs.

The Partnership's other income is a result of a cash bonus paid to the Partnership under a farmout agreement. The farmout agreement allows a third party the right to drill a deep well on leasehold acerage owned by the Partnership. If the third party exercises their rights the Partnership could receive an overriding royalty interest. The amount of the cash bonus paid to the Partnership is $28,523.

Production expenses decreased from $181,341 in 2001 to $119,731 in 2002. The production expenses include variable costs associated with volume changes, repairs and labor costs associated with the wells and well sites. During 2001 some additional maintenance was performed at various sites in order to help increase and maintain production levels. During 2002 normal routine and maintenance upkeep was performed at the well site and on the individual wells.

General and administrative expenses have been segregated on the financial statements to reflect expenses paid to PrimeEnergy Management Corporation, a general partner. These expenses are charged in accordance with guidelines set forth in the Registrant's Management Agreement and are attributable to the affairs and operations of the Partnership and shall not exceed an annual amount equal to 5% of the Limited Partners capital contributions. Amounts related to both 2001 and 2002 are substantially less than the amounts allocable to the Registrant under the Partnership Agreement. Management continues to work on reducing third party costs and use in-house resources to provide efficient and timely services to the Partnership.

The Partnership records additional depreciation, depletion and amortization to the extent that net capitalized costs exceed the undiscounted future net cash flows attributable to the Partnership properties. The Partnership was not required to revise the property basis in either 2001 or through the third quarter of 2002. There were no additional capitalized well-related expenditures during the first nine months of 2002.

PART II

Items 1 through 5 have been omitted in that each item is either inapplicable or the answer is negative.

Item 6: Exhibits and Reports on Form 8-K

(a) Exhibit 99: Certification Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant To Section 906 Of The Sarbanes-Oxley Act of 2002

(b)Form 8-K: The Partnership was not required to file any reports on Form 8-K and no such form was filed during the period covered by this report.

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S I G N A T U R E S

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

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Balance Sheets

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Operations

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Operations

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Operations

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Operations

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Changes in Partners' Equity

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Changes in Partners' Equity

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York Limited Partnership)

Statement of Cash Flows

(unaudited)

See accompanying note to the financial statements.

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STERLING DRILLING FUND 1983-1

(a New York limited partnership)

Note to Financial Statements

September 30, 2002

1. The accompanying statements for the period ending September 30, 2002 are unaudited but reflect all adjustments necessary to present fairly the results of operations.