<PAGE>
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                                  UNITED STATES
                       SECURITIES AND EXCHANGE COMMISSION
                             WASHINGTON, D.C. 20549


                                    FORM 10-Q


                QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
                     OF THE SECURITIES EXCHANGE ACT OF 1934


FOR THE QUARTER ENDED SEPTEMBER 30, 2001             COMMISSION FILE NO. 0-20998



                        KELLEY PARTNERS 1992 DEVELOPMENT
                                DRILLING PROGRAM
             (EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)



                  TEXAS                                          76-0373428
     (STATE OR OTHER JURISDICTION OF                          (I.R.S. EMPLOYER
     INCORPORATION OR ORGANIZATION)                          IDENTIFICATION NO.)


            1001 MCKINNEY ST.
                SUITE 900
             HOUSTON, TEXAS                                         77002
(ADDRESS OF PRINCIPAL EXECUTIVE OFFICES)                         (ZIP CODE)


       REGISTRANT'S TELEPHONE NUMBER, INCLUDING AREA CODE: (713) 652-5200


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


================================================================================
<PAGE>
                KELLEY PARTNERS 1992 DEVELOPMENT DRILLING PROGRAM
                                      INDEX

<TABLE>
<CAPTION>

                                                                                                          PAGE
                                                                                                          ----
<S>   <C>                                                                                                  <C>
PART I.  FINANCIAL INFORMATION

      Item 1. Financial Statements:
      Balance Sheets as of December 31, 2000 and September 30, 2001 (unaudited)..........................   2

      Statements of Income for the three months and nine months ended
         September 30, 2000 and 2001 (unaudited).........................................................   3

      Statements of Cash Flows for the nine months ended September 30, 2000 and 2001 (unaudited).........   4

      Notes to Financial Statements (unaudited)..........................................................   5

      Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations......   7

PART II.  OTHER INFORMATION..............................................................................  10
</TABLE>







                                       1
<PAGE>

                          PART I. FINANCIAL INFORMATION


ITEM 1.  FINANCIAL STATEMENTS

                KELLEY PARTNERS 1992 DEVELOPMENT DRILLING PROGRAM
                                 BALANCE SHEETS
                                 (IN THOUSANDS)

<TABLE>
<CAPTION>
                                                                         DECEMBER 31,    SEPT. 30,
                                                                             2000          2001
                                                                         ------------    ---------
                                                                                (UNAUDITED)
<S>                                                                        <C>           <C>
ASSETS:
   Cash and cash equivalents .........................................     $     --      $     --
   Accounts receivable - trade .......................................           37            36
   Accounts receivable - affiliates ..................................           47           244
                                                                           --------      --------
   Total current assets ..............................................           84           280
                                                                           --------      --------

   Oil and gas properties, successful efforts method:
     Properties subject to amortization ..............................       41,443        41,461
     Less:  Accumulated depreciation, depletion and amortization .....      (40,516)      (40,577)
                                                                           --------      --------
   Total oil and gas properties ......................................          927           884
                                                                           --------      --------
Total assets .........................................................     $  1,011      $  1,164
                                                                           ========      ========

LIABILITIES:
   Accounts payable and accrued expenses .............................     $     85      $     49
                                                                           --------      --------
Total current liabilities ............................................           85            49
                                                                           --------      --------
Total liabilities ....................................................           85            49
                                                                           --------      --------

PARTNERS' EQUITY:
   LP Unitholders' equity ............................................           67            85
   GP Unitholders' equity ............................................          822           985
   Managing and special general partners' equity .....................           37            45
                                                                           --------      --------
Total partners' equity ...............................................          926         1,115
                                                                           --------      --------
Total liabilities and partners'equity ................................     $  1,011      $  1,164
                                                                           ========      ========
</TABLE>


                       See Notes to Financial Statements.


                                       2
<PAGE>
                KELLEY PARTNERS 1992 DEVELOPMENT DRILLING PROGRAM
                              STATEMENTS OF INCOME
                      (IN THOUSANDS, EXCEPT PER UNIT DATA)
                                   (UNAUDITED)

<TABLE>
<CAPTION>
                                                       THREE MONTHS ENDED       NINE MONTHS ENDED
                                                            SEPT. 30,               SEPT. 30,
                                                       ------------------      ------------------
                                                         2000        2001        2000        2001
                                                       ------      ------      ------      ------
<S>                                                    <C>         <C>         <C>         <C>
REVENUES:
   Oil and gas sales ............................      $  202      $  174      $  574      $  701
                                                       ------      ------      ------      ------
   Total revenues ...............................         202         174         574         701
                                                       ------      ------      ------      ------

EXPENSES:
   Production expenses ..........................          47          31         171         119
   Severance taxes ..............................          15          16          24          21
   General and administrative expenses ..........          21           8          54          34
   Interest expenses ............................          --          --           6          --
   Depreciation, depletion and amortization .....          27          19          93          61
                                                       ------      ------      ------      ------
   Total expenses ...............................         110          74         348         235
                                                       ------      ------      ------      ------
Net income ......................................      $   92      $  100      $  226      $  466
                                                       ======      ======      ======      ======


Net income allocable to LP and GP unitholders ...      $   88      $   96      $  217      $  448
                                                       ======      ======      ======      ======

Net income allocable to managing and
   special general partners .....................      $    4      $    4      $    9      $   18
                                                       ======      ======      ======      ======

Net income per LP and GP unit ...................      $  .01      $  .01      $  .01      $  .03
                                                       ======      ======      ======      ======

Average LP and GP units outstanding .............      16,033      16,033      16,033      16,033
                                                       ======      ======      ======      ======
</TABLE>


                       See Notes to Financial Statements.




                                       3
<PAGE>
                KELLEY PARTNERS 1992 DEVELOPMENT DRILLING PROGRAM
                            STATEMENTS OF CASH FLOWS
                                 (IN THOUSANDS)
                                   (UNAUDITED)

<TABLE>
<CAPTION>
                                                                            NINE MONTHS ENDED
                                                                                 SEPT. 30,
                                                                            ------------------
                                                                             2000        2001
                                                                            ------      ------
<S>                                                                         <C>         <C>
OPERATING ACTIVITIES:
   Net income ........................................................      $  226      $  466
   Adjustments to reconcile net income to net cash
    provided by operating activities:
     Depreciation, depletion and amortization ........................          93          61
   Changes in operating assets and liabilities:
     Increase in accounts receivable .................................        (232)       (196)
     Increase (decrease) in accounts payable and accrued expenses ....          17         (36)
                                                                            ------      ------
   Net cash provided by operating activities .........................         104         295
                                                                            ------      ------

INVESTING ACTIVITIES:
   Capital expenditures ..............................................          62         (18)
                                                                            ------      ------
   Net cash provided by (used in) investing activities ...............          62         (18)
                                                                            ------      ------

FINANCING ACTIVITIES:
   Distribution to partners ..........................................          --        (277)
   Principal payments on long-term debt ..............................        (166)         --
                                                                            ------      ------
   Net cash used in financing activities .............................        (166)       (277)
                                                                            ------      ------
Increase (decrease) in cash and cash equivalents .....................          --          --
Cash and cash equivalents, beginning of period .......................          --          --
                                                                            ------      ------
Cash and cash equivalents, end of period .............................      $   --      $   --
                                                                            ======      ======
</TABLE>



                       See Notes to Financial Statements.



                                       4
<PAGE>
                KELLEY PARTNERS 1992 DEVELOPMENT DRILLING PROGRAM
                    NOTES TO FINANCIAL STATEMENTS (UNAUDITED)

NOTE 1 - BASIS OF PRESENTATION

         General. The accompanying unaudited interim financial statements of
Kelley Partners 1992 Development Drilling Program (the "Partnership") have been
prepared pursuant to the rules and regulations of the Securities and Exchange
Commission in accordance with accounting principles generally accepted in the
United States of America for interim financial information. These financial
statements reflect all adjustments (consisting solely of normal recurring
adjustments) necessary for a fair presentation of the results for the interim
periods presented. The results of operations for the three months and nine
months ended September 30, 2001 are not necessarily indicative of results to be
expected for the full year. The accounting policies followed by the Partnership
are set forth in Note 1 to the financial statements included in its Annual
Report on Form 10-K for the year ended December 31, 2000. These unaudited
interim financial statements should be read in conjunction with the audited
financial statements and notes thereto included in the Partnership's 2000 Annual
Report on Form 10-K.

         Derivative and Hedge Accounting. Historically, Contour Energy Co. has
entered into hedge agreements on behalf of the Partnership to protect against
commodity price declines, including production volumes for the third quarter and
the first nine months of 2000. Beginning in 2001, due to small production
volumes, the Partnership production will no longer be hedged.

         Through natural gas price swap agreements and collars, the Partnership
hedged approximately 94% and 65% of its natural gas production for the third
quarter of 2000 and the first nine months of 2000, respectively. Through crude
oil price swap agreements and collars, the Partnership hedged approximately 48%
and 62% of its crude oil production for the three and nine months ended
September 30, 2000, respectively. No natural gas or crude oil was hedged in the
three months and nine months ended September 30, 2001. Hedging activities
decreased Partnership revenues by $36,000 and $56,000 for the three months and
nine months ended September 30, 2000,respectively, as compared to estimated
revenues had no hedging activities been conducted.

         The Partnership adopted Statement of Financial Accounting Standards No.
133, "Accounting for Derivative Instruments and Hedging Activities" ("SFAS 133")
effective January 1, 2001. As of January 1, 2001, the Partnership was not a
party to any derivative instruments and as such there was no impact on its
financial statements as a result of the adoption of SFAS 133.

         In June 2001, the Derivatives Implementation Group ("DIG") issued
Statement 133 Implementation Issue No. G20 ("G20") titled "Cash Flow Hedges:
Assessing and Measuring the Effectiveness of a Purchase Option Used in a Cash
Flow Hedge". G20 states, if an entity designates a purchased option (including a
combination of options that comprise either a net purchased option of a
zero-cost collar) in hedging the exposure to variability in expected future cash
flows (i.e. natural gas or crude oil prices) and the entity documents that the
hedge relationship is perfectly effective, it may report the change in the fair
value of the purchase option through Other Comprehensive Income ("OCI"). The
amount reported through accumulated OCI would be reclassified through earnings
effecting the period covered by the purchase option. The effective date of
implementation guidance in this issue is the first day of the first fiscal
quarter after August 10, 2001. The Partnership plans to implement G20 during the
fourth quarter, and expects no impact on its financial statements as a result of
the adoption.

NOTE 2 - NEW ACCOUNTING PRONOUNCEMENTS

         In the fourth quarter of 2000, the Partnership adopted Emerging Issues
Task Force Issue No. 00-10 ("EITF No. 00-10") accounting for Shipping and
Handling Fees and Costs. EITF No. 00-10 addresses how shipping and handling fees
should be classified in the income statement. As a result of EITF No. 00-10, the
Partnership has reclassified its transportation and compression expenses from
oil and gas revenues to lease operating expenses. As a result, $2,000 and $5,000
of expenses were reclassified from oil and gas revenues to lease operating
expenses for the three months and nine months ended September 30, 2000,
respectively.


                                       5
<PAGE>
         In July 2001, the Financial Accounting Standards Board ("FASB") issued
two new pronouncements: Statement of Financial Accounting Standards ("SFAS") No.
141, "Business Combinations", and SFAS No. 142, "Goodwill and Other Intangible
Assets". SFAS 141 prohibits the use of the pooling-of-interest method for
business combinations initiated after June 30, 2001 and also applies to all
business combinations accounted for by the purchase method that are completed
after June 30, 2001. SFAS 142, effective for fiscal years beginning after
December 15, 2001, addresses financial accounting and reporting for acquired
goodwill and other intangible assets and supersedes APB Opinion No. 17,
Intangible Assets. It addresses how intangible assets that are acquired
individually or with a group of other assets (but not those acquired in a
business combination) should be accounted for in financial statements upon their
acquisition. This Statement also addresses how goodwill and other intangible
assets should be accounted for after they have been initially recognized in the
financial statements. The Partnership expects no impact on its financial
statements from the adoption of these standards.

         In August and October 2001, the FASB issued SFAS No. 143, "Accounting
for Asset Retirement Obligations" and SFAS No. 144, "Accounting for Impairment
or Disposal of Long-Lived Assets". SFAS 143 requires entities to record the fair
value of a liability for an asset retirement obligation in the period in which
it is incurred and a corresponding increase in the carrying amount of the
related long-lived asset. Subsequently, the asset retirement costs should be
allocated to expense using a systematic and rational method. SFAS 143 is
effective for fiscal years beginning after June 15, 2002. SFAS 144 addresses
financial accounting and reporting for the impairment of long-lived assets and
for long-lived assets to be disposed of. It supersedes, with exceptions, SFAS
121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed of", and is effective for fiscal years beginning after
December 15, 2001. The Partnership is currently assessing the impact of SFAS No.
143 and No. 144 and cannot yet reasonably estimate the impact, if any,
these statements will have on its financial statements upon adoption.












                                       6
<PAGE>
ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
         RESULTS OF OPERATIONS

GENERAL

         In 1992, Kelley Partners 1992 Development Drilling Program (the
"Partnership") issued units of limited and general partner interests ("Units").
The Units represent 96.04% of the total interests in the Partnership. In
addition, the Partnership issued managing and special general partner interests
representing 3.96% of the total interests in the Partnership. At September 30,
2001, Contour Energy E&P, Inc. (formerly Kelley Oil Corporation), managing
general partner of the Partnership and a wholly owned subsidiary of Contour
Energy Co. ("Contour") owns 91.82% of the Units and a 3.94% managing general
partnership interest.

RECENT DEVELOPMENTS

         Drilling Operations. Since inception, the Partnership participated in
drilling 39 gross (15.23 net) wells, of which 30 gross (11.07 net) wells were
found productive and 9 gross (4.16 net) wells were dry.

         Hedging and Derivative Activities. Historically, Contour has entered
into hedge agreements on behalf of the Partnership to protect against commodity
price declines, including production volumes for the third quarter and the first
nine months of 2000. Beginning 2001, due to small production volumes, the
Partnership production will no longer be hedged.

         Through natural gas price swap agreements, the Partnership hedged
approximately 94% and 65% of the its natural gas production for the third
quarter of 2000 and the first nine months of 2000, respectively. Through crude
oil price swap agreements, the Partnership hedged approximately 48% and 62% of
its crude oil production for the three and nine months ended September 30, 2000,
respectively. No natural gas or crude oil was hedged in the three months and
nine months ended September 30, 2001. Hedging activities decreased Partnership
revenues by $36,000 and $56,000 for the three months and nine months ended
September 30, 2000, respectively, as compared to estimated revenues had no
hedging activities been conducted.

RESULTS OF OPERATIONS

         Three Months Ended September 30, 2001 and 2000. Oil and gas revenues
decreased 14% to $174,000 for the third quarter of 2001 compared to $202,000 in
the corresponding quarter of 2000 primarily resulting from lower natural gas
production and lower natural gas and crude oil prices. Production of natural gas
decreased 10% from 35,117 Mcf in the third quarter of 2000 to 31,518 Mcf in the
current quarter due to natural production declines in the Partnership's
producing areas. The average price of natural gas decreased 6% to $3.15 per Mcf
in the third quarter of 2001 from $3.35 per Mcf in the same period last year.
Production of crude oil in the current quarter totaled 2,811 barrels, with an
average sales price of $26.57 per barrel compared to 2,754 barrels at $30.64 per
barrel in the same quarter last year, representing a volume increase of 2% and a
price decrease of 13%.

         Production expenses and severance taxes were $47,000 in the current
quarter versus $62,000 in the third quarter of 2000, a decrease of 24%. The
decrease was due primarily to lower lifting costs relating in part to declines
in production. On a unit of production basis, these expenses decreased to $0.97
per Mcfe in the third quarter of 2001 from $1.20 per Mcfe in the same quarter of
2000.

         General and administrative ("G&A") expenses decreased to $8,000 in the
current quarter, or 62%, from $21,000 in the third quarter of 2000. Lower
current period Partnership production activity caused the decline in G&A
expenses charged by Contour Energy E&P, Inc. On a unit of production basis,
these expenses decreased from $0.41 per Mcfe in the third quarter of 2000 to
$0.17 per Mcfe in the current quarter.

         Depreciation, depletion and amortization ("DD&A") expenses decreased
30% from $27,000 in the third quarter of 2000 to $19,000 in the current quarter
due to lower production levels and lower depletion rates. On a unit of
production basis, DD&A expenses decreased to $0.39 per Mcfe in the third quarter
of 2001 from $0.52 per Mcfe in the same quarter last year.


                                       7
<PAGE>
         The Partnership recognized net income of $100,000 or $0.01 per Unit for
the third quarter of 2001 compared to net income of $92,000 or $0.01 per Unit
for the third quarter of 2000. The reasons for the variance between the third
quarter of 2001 and the third quarter of 2000 are described in the foregoing
discussion.

         Nine Months Ended September 30, 2001 and 2000. Oil and gas revenues
increased 22% to $701,000 for the first nine months of 2001 compared to $574,000
in the corresponding period of 2000 as a result of higher natural gas prices,
partially offset by lower natural gas and crude oil production. Production of
natural gas decreased 9% from 108,684 Mcf in the first nine months of 2000 to
98,605 Mcf in the current period primarily due to natural production declines in
the Partnership's production areas. The average price of natural gas was $5.31
per Mcf in the first nine months of 2001 compared to $3.17 per Mcf in the prior
year. Production of crude oil in the current period totaled 6,671 barrels, with
an average sales price of $26.99 per barrel compared to 8,018 barrels at $28.83
per barrel in the same period last year, representing a 6% decrease in prices
and a volume decrease of 17% due to natural production declines in the
Partnership's producing areas.

         Production expenses and severance taxes were $140,000 in the current
period versus $195,000 in the first nine months of 2000, a decrease of 28%. The
decrease was due primarily to lower lifting costs and severance taxes in the
first nine months of 2001 resulting in part from lower natural gas and crude oil
production. On a unit of production basis, these expenses decreased to $1.01 per
Mcfe in the first nine months of 2001 from $1.24 per Mcfe in the year-earlier
period.

         G&A expenses of $34,000 in the current period decreased 37% from
$54,000 in the first nine months of 2000. Lower current period Partnership
production activity caused the decline in G&A expenses charged by Contour Energy
E&P, Inc. to the Partnership. On a unit of production basis, G&A expenses
decreased from $0.34 per Mcfe in the first nine months of 2000 to $0.25 per Mcfe
in the current period.

         In the first nine months of 2000, the Partnership incurred interest
expenses of $6,000, on a loan advanced to it by Contour Energy E&P, Inc.
(formerly Kelley Oil Corporation) in August 1994 ("Initial Loan") to fund part
of its drilling expenditures in excess of contributed capital. There was no
interest expense in the first nine months of 2001 as the final payment on the
Initial Loan was made in the second half of 2000.

         DD&A expenses decreased 34% from $93,000 in the first nine months of
2000 to $61,000 in the current period due to lower current period production and
lower depletion rates. On a unit of production basis, DD&A expenses decreased to
$0.44 per Mcfe in the first nine months of 2001 from $0.59 per Mcfe in the same
period last year.

         The Partnership recognized net income of $466,000 or $0.03 per Unit for
the first nine months of 2001. For the first nine months of 2000, the
Partnership recognized net income of $226,000 or $0.01 per Unit. The reasons for
the variance between the first nine months of 2001 and the first nine months of
2000 are described in the foregoing discussion.

         The results of operations for the quarter and nine months ended
September 30, 2001 are not necessarily indicative of the Partnership's operating
results to be expected for the full year.

LIQUIDITY AND CAPITAL RESOURCES

         Liquidity. Net cash provided by the Partnership's operating activities
during the first nine months of 2001, as reflected on its statement of cash
flows, totaled $295,000. During the period, funds used in investing activities
were comprised of capital expenditures of $18,000, and funds used in financing
activities consisted of $277,000 distributed to partners. As a result of these
activities, the Partnership's cash and cash equivalents remained unchanged from
December 31, 2000.

         Capital Resources. The Partnership has completed its development stage.
Accordingly, cash flow from operations should be adequate to meet its expected
capital and general working capital needs.

         Distribution Policy. The Partnership maintains a policy of distributing
cash that is not required for the conduct of Partnership business to unitholders
on a quarterly basis. During the first nine months of 2001, earnings
distributions were paid to the managing and special general partners and
unitholders in the amounts of $11,000 and $266,000, or $0.02 per Unit,
respectively. However, future distributions are contingent on future operating
results.

                                       8
<PAGE>
         Inflation and Changing Prices. Oil and natural gas prices, as with most
commodities, are highly volatile, have fluctuated during recent years and
generally have not followed the same pattern as inflation.

         Accounting Pronouncements. In the fourth quarter of 2000, the
Partnership adopted Emerging Issues Task Force Issue No. 00-10 ("EITF No.
00-10") accounting for Shipping and Handling Fees and Costs. EITF No. 00-10
addresses how shipping and handling fees should be classified in the income
statement. As a result of EITF No. 00-10, the Partnership has reclassified its
transportation and compression expenses from oil and gas revenues to lease
operating expenses. As a result, $2,000 and $5,000 of expenses were reclassified
from oil and gas revenues to lease operating expenses for the three months and
nine months ended September 30, 2000, respectively.

         In July 2001, the Financial Accounting Standards Board ("FASB") issued
two new pronouncements: Statement of Financial Accounting Standards ("SFAS") No.
141, "Business Combinations", and SFAS No. 142, "Goodwill and Other Intangible
Assets". SFAS 141 prohibits the use of the pooling-of-interest method for
business combinations initiated after June 30, 2001 and also applies to all
business combinations accounted for by the purchase method that are completed
after June 30, 2001. SFAS 142, effective for fiscal years beginning after
December 15, 2001, addresses financial accounting and reporting for acquired
goodwill and other intangible assets and supersedes APB Opinion No. 17,
Intangible Assets. It addresses how intangible assets that are acquired
individually or with a group of other assets (but not those acquired in a
business combination) should be accounted for in financial statements upon their
acquisition. This Statement also addresses how goodwill and other intangible
assets should be accounted for after they have been initially recognized in the
financial statements. The Partnership expects no impact on its financial
statements from the adoption of these standards.

         In August and October 2001, the FASB issued SFAS No. 143, "Accounting
for Asset Retirement Obligations" and SFAS No. 144, "Accounting for Impairment
or Disposal of Long-Lived Assets". SFAS 143 requires entities to record the fair
value of a liability for an asset retirement obligation in the period in which
it is incurred and a corresponding increase in the carrying amount of the
related long-lived asset. Subsequently, the asset retirement costs should be
allocated to expense using a systematic and rational method. SFAS 143 is
effective for fiscal years beginning after June 15, 2002. SFAS 144 addresses
financial accounting and reporting for the impairment of long-lived assets and
for long-lived assets to be disposed of. It supersedes, with exceptions, SFAS
121, "Accounting for the Impairment of Long-Lived Assets and for Long-Lived
Assets to be Disposed of", and is effective for fiscal years beginning after
December 15, 2001. The Partnership is currently assessing the impact of SFAS No.
143 and No. 144 and cannot yet reasonably estimate the impact, if any, these
statements will have on its financial statements upon adoption.






                                       9
<PAGE>
FORWARD-LOOKING STATEMENTS

         Statements contained in this Report and other materials filed or to be
filed by the Partnership with the Securities and Exchange Commission (as well as
information included in oral or other written statements made or to be made by
the Partnership or its representatives) that are forward-looking in nature are
intended to be "forward-looking statements" within the meaning of Section 27A of
the Securities Act of 1933, as amended, and Section 21E of the Securities
Exchange Act of 1934, as amended, relating to matters such as anticipated
operating and financial performance, business prospects, developments and
results of the Partnership. Actual performance, prospects, developments and
results may differ materially from any or all anticipated results due to
economic conditions and other risks, uncertainties and circumstances partly or
totally outside the control of the Partnership, including rates of inflation,
natural gas prices, uncertainty of reserve estimates, rates and timing of future
production of oil and gas, exploratory and development activities, acquisition
risks, changes in the level and timing of future costs and expenses related to
drilling and operating activities and those risk factors described on pages 9
and 10 of the Partnership's Annual Report on Form 10-K for the fiscal year ended
December 31, 2000.

         Words such as "anticipated," "expect," "estimate," "project" and
similar expressions are intended to identify forward-looking statements.
Forward-looking statements include the risk factors described in the
Partnership's Form 10-K mentioned above.


                           PART II. OTHER INFORMATION


ITEM 6.  EXHIBITS AND REPORTS ON FORM 8-K

         (a)  Exhibits:

              EXHIBIT
              NUMBER:      EXHIBIT
              -------      -------

               None

         (b)  Reports on Form 8-K:

              No reports on Form 8-K were filed by the Registrant during the
              third quarter of 2001.











                                       10
<PAGE>
                                   SIGNATURES

         Pursuant to the requirements 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 authorized.



                                         KELLEY PARTNERS 1992
                                         DEVELOPMENT DRILLING PROGRAM

                                         By:  CONTOUR ENERGY E&P, INC.
                                              Managing General Partner


Date: November 14, 2001                  By:       /s/Rick G. Lester
                                            ------------------------------------
                                                      Rick G. Lester
                                                  Chief Financial Officer
                                                 (Duly Authorized Officer)
                                               (Principal Accounting Officer)