Washington D.C. 20549

                     OF THE SECURITIES EXCHANGE ACT OF 1934

                  For the quarterly period ended March 31, 2002


                     OF THE SECURITIES EXCHANGE ACT OF 1934

               For the transition period from ________ to ________

                          Commission File Number 0-9494

                          ASPEN EXPLORATION CORPORATION
                (Exact Name of Aspen as Specified in its Charter)

              Delaware                                      84-0811316
              --------                                      ----------
   (State or other jurisdiction of                        (IRS Employer
   incorporation or organization)                       Identification No.)

    Suite 208, 2050 S. Oneida St.,
          Denver, Colorado                                   80224-2426
          ----------------                                   ----------
(Address of Principal Executive Offices)                     (Zip Code)

                    Issuer's telephone number: (303) 639-9860

Indicate by check mark whether Aspen (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 Aspen was required to file
such reports), and (2) has been subject to such filing requirements for the past
90 days.
                              Yes [ X ]   No [   ]

Indicate the number of shares outstanding of each of the Issuer's classes of
common stock as of the latest practicable date.

           Class                                     Outstanding at May 10, 2002
           -----                                     ---------------------------
Common stock, $.005 par value                                  5,863,828


     Item 1. Financial Statements

                           CONSOLIDATED BALANCE SHEETS

                                                       March 31,       June 30,
                                                          2002           2001
                                                          ----           ----
                                                      (Unaudited)     (Audited)
Current Assets:

Cash and cash equivalents, including $1,210,075 and
$2,636,342 of invested cash at March 31, 2002 and
June 30, 2001 respectively ........................   $ 1,265,013    $ 2,695,583

Precious metals ...................................        18,823         18,823

Accounts receivable, trade ........................       244,838        554,159

Accounts receivable - related party (Note 7) ......           -0-         20,000

Prepaid expenses ..................................        51,001         14,898
                                                      -----------    -----------

     Total current assets .........................     1,579,675      3,303,463
                                                      -----------    -----------

Investment in oil and gas properties, at cost
(full cost method of accounting) ..................     4,899,510      4,297,306

Less accumulated depletion and valuation allowance     (2,256,413)    (1,921,413)
                                                      -----------    -----------

                                                        2,643,097      2,375,893
                                                      -----------    -----------

Property and equipment, at cost:

Furniture, fixtures and vehicles ..................       109,653        104,368

Less accumulated depreciation .....................       (41,154)       (28,133)
                                                      -----------    -----------
                                                           68,499         76,235
                                                      -----------    -----------
Cash surrender value, life insurance ..............       239,095        239,095
                                                      -----------    -----------

     TOTAL ASSETS .................................   $ 4,530,366    $ 5,994,686
                                                      ===========    ===========

                              (Statement Continues)
                 See notes to Consolidated Financial Statements


                     CONSOLIDATED BALANCE SHEETS (Continued)


                                                     March 31,        June 30,
                                                        2002            2001
                                                        ----            ----
                                                    (Unaudited)      (Audited)
Current liabilities:

Accounts payable and accrued expenses ..........    $    73,157     $ 1,036,715

Advances from joint owners .....................        156,838         444,232
                                                    -----------     -----------

Total current liabilities ......................        229,995       1,480,947

Deferred income tax payable ....................        179,200         179,200
                                                    -----------     -----------
Total liabilities ..............................        409,195       1,660,147
                                                    -----------     -----------

Stockholders' equity:

Common stock, $.005 par value:
    Authorized: 50,000,000 shares
    Issued: At March 31, 2002: 5,863,828
    and June 30, 2001: 5,812,205 ...............         29,320          29,060

Capital in excess of par value .................      6,024,513       6,015,279

Accumulated deficit ............................     (1,919,161)     (1,692,592)

Deferred compensation ..........................        (13,501)        (17,208)
                                                    -----------     -----------

Total stockholders' equity .....................      4,121,171       4,334,539
                                                    -----------     -----------

Total liabilities and stockholders' equity .....    $ 4,530,366     $ 5,994,686
                                                    ===========     ===========

                 See Notes to Consolidated Financial Statements


                                   CONSOLIDATED STATEMENTS OF OPERATIONS

                                                           Three Months Ended           Nine Months Ended
                                                                March 31,                    March 31,
                                                                ---------                    ---------
                                                           2002           2001          2002           2001
                                                           ----           ----          ----           ----
  Oil and gas ......................................   $   124,257    $ 1,109,992   $   513,444    $ 2,688,142
  Management fees ..................................        23,632         26,135        91,269        138,397
  Interest and other, net ..........................        10,395         43,387        46,600         72,533
                                                       -----------    -----------   -----------    -----------
Total Revenues .....................................       158,284      1,179,514       651,313      2,899,072
                                                       -----------    -----------   -----------    -----------

Costs and expenses:
  Oil and gas production ...........................        34,415         27,058       102,688        151,585
  Depreciation, depletion and amortization .........       121,741         77,000       348,020        220,000
  Aspen Power Systems expense ......................             0              0        25,500              0
  Selling, general and administrative ..............       164,246        146,322       471,725        449,805
  Interest expense .................................           479             70           479          7,949
                                                       -----------    -----------   -----------    -----------

Total Costs and Expenses ...........................       320,881        250,450       948,412        829,339
                                                       -----------    -----------   -----------    -----------
Net income (loss) before taxes .....................   $  (162,597)   $   929,064   $  (297,099)   $ 2,069,733
                                                       -----------    -----------   -----------    -----------
Provision for (recovery of) income taxes
Notes 2 and 6 ......................................       (70,530)        82,165       (70,530)       162,165
                                                       -----------    -----------   -----------    -----------
Net income (loss) ..................................   $   (92,067)   $   846,899   $  (226,569)   $ 1,907,568
                                                       ===========    ===========   ===========    ===========
Basic earnings (loss) per common share .............   $      (.02)   $       .16   $      (.04)   $       .35
                                                       ===========    ===========   ===========    ===========
Diluted earnings (loss) per common
share ..............................................   $      (.02)   $       .15   $      (.04)   $       .34
                                                       ===========    ===========   ===========    ===========
Basic weighted average number of
common shares outstanding ..........................     5,831,800      5,401,678     5,831,800      5,401,678
                                                       ===========    ===========   ===========    ===========
Diluted weighted average number of
common shares outstanding ..........................     6,022,414      5,661,678     6,022,414      5,661,678
                                                       ===========    ===========   ===========    ===========

                                  The accompanying notes are an integral
                                         part of these statements.



                                                         Nine months ended March 31,
                                                             2002           2001
                                                         -----------    -----------
Cash flows from operating activities:

Net income (loss) ....................................   $  (226,569)   $ 1,907,567

Adjustments to reconcile net income
  to net cash provided by operating activities:

  Depreciation, depletion & amortization .............       348,020        220,000
  Amortization of deferred compensation ..............        13,200         13,203

Changes in assets and liabilities:

  (Increase) decrease in accounts receivable .........       329,321        (36,018)
  (Increase) decrease in prepaid expense .............       (36,103)         3,616
  Increase (decrease) in accounts payable and accrued
    expense ..........................................    (1,250,950)       279,272
                                                         -----------    -----------
  Net cash provided (used) by operating activities ...      (823,081)     2,387,640
                                                         -----------    -----------

Cash flows from investing activities:

  Additions to oil & gas properties ..................      (628,244)      (420,138)
  Purchase of office equipment & vehicle .............        (5,285)       (21,133)
  Sale of idle equipment at cost .....................             0          6,000
  Sale of oil and gas properties .....................        26,040              0
                                                         -----------    -----------

  Net cash (used) by investing activities ............      (607,489)      (435,271)
                                                         -----------    -----------

Cash flows from financing activities:

  Repayment of notes payable .........................             0       (236,746)
                                                         -----------    -----------

  Net cash used in financing activities ..............             0       (236,746)
                                                         -----------    -----------

  Net increase (decrease) in cash and cash equivalents    (1,430,570)     1,715,623

  Cash and cash equivalents, beginning of year .......     2,695,583        507,382
                                                         -----------    -----------

  Cash and cash equivalents, end of period ...........   $ 1,265,013    $ 2,223,005
                                                         -----------    -----------

  Interest paid ......................................   $       479    $     7,949
                                                         ===========    ===========

  Income taxes paid (refund) .........................   $   (70,530)   $    83,000
                                                         ===========    ===========

                      The accompanying notes are an integral
                             part of these statements.


                          ASPEN EXPLORATION CORPORATION

                   Notes to Consolidated Financial Statements

                                 March 31, 2002


     The accompanying financial statements are unaudited. However, in our
     opinion, the accompanying financial statements reflect all adjustments,
     consisting of only normal recurring adjustments, necessary for fair
     presentation. Interim results of operations are not necessarily indicative
     of results for the full year. These financial statements should be read in
     conjunction with our Annual Report on Form 10-KSB for the year ended June
     30, 2001.

     Except for the historical information contained in this Form 10-QSB, this
     Form contains forward-looking statements that involve risks and
     uncertainties. Our actual results could differ materially from those
     discussed in this Report. Factors that could cause or contribute to such
     differences include, but are not limited to, those discussed in this Report
     and any documents incorporated herein by reference, as well as the Annual
     Report on Form 10-KSB for the year ended June 30, 2001.


     In February 1997, the Financial Accounting Standards Board issued Statement
     of Financial Accounting Standards No. 128 ("SFAS No. 128"), addressing
     earnings per share. SFAS No. 128 changed the methodology of calculating
     earnings per share and renamed the two calculations basic earnings per
     share and diluted earnings per share. The calculations differ by
     eliminating any common stock equivalents (such as stock options, warrants,
     and convertible preferred stock) from basic earnings per share and changes
     certain calculations when computing diluted earnings per share. We adopted
     SFAS No. 128 in fiscal year 1998.



     The following is a reconciliation of the numerators and denominators used
     in the calculations of basic and diluted earnings per share for the six
     months ended March 31, 2002 and 2001:

                                        March 31,  2002                       March 31, 2001
                              -----------------------------------    --------------------------------
                                                           Per                                  Per
                                 Net                      Share         Net                    Share
                                Income        Shares      Amount       Income       Shares     Amount
                              ----------    ----------    -------    ----------   ----------   ------
Basic earnings per share:

  Net income and
  share amounts ...........   $ (226,569)    5,831,800    $  (.04)   $1,907,568    5,401,678   $  .35

  Dilutive securities
  stock options ...........                    776,000                               380,000

  Repurchased shares ......                   (585,386)                             (120,000)
                              ----------    ----------    -------    ----------   ----------   ------
Diluted earnings per share:

  Net income and assumed
  share conversion ........   $ (226,569)    6,022,414    $  (.04)   $1,907,568    5,661,678   $  .34
                              ==========    ==========    =======    ==========   ==========   ======

     On December 17, 2001 a director exercised his stock options for 80,000
     shares of our common stock at an average exercise price of $0.26 per share.
     As consideration for the option shares purchased, the director surrendered
     common stock with a fair value equal to the exercise price of the option
     shares. The fair value of the shares surrendered was based on a ten-day
     average bid price immediately prior to the exercise date. Total shares
     surrendered were 28,377. The effect of this transaction is a net increase
     to the common stock par value of $260 and a corresponding decrease to
     additional paid in capital of $260. The filing of this stock option
     exercise with the Securities and Exchange Commission by Form 4 was not
     timely filed.

     On March 14, 2002 we issued options to purchase 676,000 shares of our
     common stock at $0.57 per share to our officers, directors, employees and
     consulting accountant as follows:

                        R. V. Bailey            150,000
                        Robert A. Cohan         250,000
                        Robert F. Sheldon       150,000
                        Ray K. Davis             75,000
                        Judith L. Shelton        51,000

                                 Total Shares   676,000

     Bailey, Sheldon, Davis and Shelton options will vest one-third each on
     August 15, 2003, 2004 and 2005. The Cohan options will vest one-fifth each
     on August 15, 2003 through 2007.



     The options to the consultant were valued using the fair value method of
     SFAS No. 123 as calculated by the Black-Scholes option-pricing model with
     the following weighted average assumptions: no dividend yield, expected
     volatility of 13.88%, a risk free interest rate of 8.50% and an expected
     life of 4.5 years. The resulting compensation of $12,936 will be included
     in operating expense as the options vest.

     The options to officers, directors and employees were valued using the
     intrinsic method of APB No. 25, resulting in no compensation expense
     recorded in connection with these options. The adjustment to net income for
     compensation expense would be recorded under SFAS No. 123 as the options
     vest. Therefore, there is no proforma effect relating to these options
     required to be disclosed under SFAS No. 123.


     We operate in one industry segment within the United States, oil and gas
     exploration and development.

     Identified assets by industry are those assets that are used in our
     operations in that industry. Corporate assets are principally cash, cash
     surrender value of life insurance, furniture, fixtures and vehicles.

     During the fourth quarter of 1998, we adopted Statement of Financial
     Accounting Standards No. 131, "Disclosures about Segments of an Enterprise
     and Related Information" (SFAS No. 131). The adoption of SFAS No. 131
     requires the presentation of descriptive information about reportable
     segments which is consistent with that made available to the management of
     the Company to assess performance.

     Our oil and gas segment derives its revenues from the sale of oil and gas
     and prospect generation and administrative overhead fees charged to
     participants in our oil and gas ventures. Corporate income is primarily
     derived from interest income on funds held in money market accounts.

     During the nine months ended March 31, 2002 there were no intersegment
     revenues. The accounting policies applied by each segment are the same as
     those used by us in general.

     There have been no differences from the last annual report in the basis of
     measuring segment profit or loss, with the exception of the elimination of
     the mineral and power plant segments which we are no longer active in and
     are not material. There have been no material changes in the amount of
     assets for any operating segment since the last annual report except for
     the oil and gas segment which sold oil and gas properties for $26,040 and
     capitalized $628,244 for the development and acquisition of oil and gas
     properties, and the corporate segment which purchased $5,285 of computer
     equipment during the period.



     Segment information consists of the following for the nine months ended
     March 31:

                         Oil and Gas   Power Plant    Corporate     Consolidated
                         -----------   -----------    ---------     ------------

           2002          $    604,713   $   -0-      $    46,600    $   651,313
           2001             2,826,539       -0-           72,533      2,899,072

Income (loss) from operations:

           2002          $    167,025    $(25,500)   $  (368,094)   $  (226,569)
           2001             2,304,789       -0-         (397,221)     1,907,568

Identifiable assets:

           2002          $  2,887,935    $  -0-      $ 1,642,431    $ 4,530,366
           2001             2,010,456       -0-        2,562,664      4,573,120

Depreciation, depletion and valuation
charged to identifiable assets:

           2002          $ (2,256,413)   $  -0-      $   (41,154)   $(2,297,567)
           2001            (1,728,589)      -0-         (140,689)    (1,869,278)

Capital expenditures:

           2002          $    628,244    $  -0-      $     5,285    $   633,529
           2001               420,138       -0-           21,133        441,271


     We derived in excess of 10% of our revenue from various sources (oil and
     gas sales) as follows:
                                  The Company

                            A          B          C          D
                            -          -          -          -
     Year ended:

        March 31, 2002      36%        --         32%        12%
        March 31, 2001      35%        12%        49%        --


     At March 31, 2002 the Company was committed to the following drilling and
     development projects in California:



     1.   Two Tehama County, California wells. The average total costs for each
          well is estimated at $520,000 with our share of the average net costs
          per well approximately $121,000.

     2.   One Colusa County, California well that is estimated to cost $755,000
          with our share of the net costs approximately $70,000, net of prospect


     The Company has made no provision for income taxes for the nine month
     period ended March 31, 2002 since it utilizes net operating loss
     carryforwards. The Company had $583,321 of such carryforwards at June 30,

     On March 26, 2002 we received a refund of overpaid income taxes of $70,530
     from the State of California for our fiscal year ended June 30, 2001.


     On October 4, 2001 the California Power Authority notified our affiliate,
     Aspen Power Systems ("APS") that no further action would be taken on APS'
     proposal to build and operate a 323 MW natural gas fired electrical
     generating plant for the State of California. Consequently, we have written
     off a $20,000 advance we provided APS, as well as an additional $5,500
     payment made to APS in the quarter ended December 31, 2001. The additional
     $5,500 payment along with a like amount from each of the other three
     participants in APS was applied to the outstanding obligations of APS at
     December 31, 2001. At December 31, 2001 we received approximately $10,000
     from APS for the services of our president R. V. Bailey. These services
     were administrative in nature and were mainly for negotiations with third
     parties for the construction of power plants in California. Future power
     plant construction opportunities in California appear remote, given current
     economic conditions, and APS has scaled back its efforts and is seeking
     other approaches to contracts and financing for power generation facilities
     in Solano County, California. There is no assurance these efforts will be

     On April 22, 2002 we closed on the purchase and sales agreement with an
     affiliated company to acquire all of its interest in 8 producing gas wells
     in Northern California. The purchase is effective January 1, 2002. The
     purchase price of these properties was approximately $118,000. We acquired
     60% of the working interest in these properties for $66,075. The balance of
     40% was acquired by affiliated investors for $51,925.

     On April 27, 2002 we commenced drilling operations on the Porter 26-2, a
     6800 foot exploratory gas well in Tehama County, California. We have
     committed to drill the Porter 26-2 and two additional wells in Tehama and
     Colusa Counties as follows:



                           Estimated                          Our Estimated
Well                       Spud Date       Total Depth        Dry Hole Cost
----                       ---------       -----------        -------------

Porter 26-2                4-27-02          6800 feet           $  80,000
Leal 22-1                  5-15-02          5600 feet              57,000
Kuppenbender 20-3          5-15-02          9000 feet              25,000

                                                                $ 162,000

     Results of these proposed drilling operations will be disclosed in future



     This should be read in conjunction with the management's discussion and
analysis of financial condition and results of operations contained in our
Annual Report on Form 10-KSB for the year ended June 30, 2001, which has been
filed with the Securities and Exchange Commission. This management's discussion
and analysis and other portions of this report contain forward-looking
statements (as such term is defined in Section 21E of the Securities Exchange
Act of 1934, as amended). These statements reflect our current expectations
regarding our possible future results of operations, performance, and
achievements. These forward-looking statements are made pursuant to the safe
harbor provisions of the Private Securities Litigation Reform Act of 1995.

     Wherever possible, we have tried to identify these forward-looking
statements by using words such as "anticipate," "believe," "estimate," "expect,"
"plan," "intend," and similar expressions. These statements reflect our current
beliefs and are based on information currently available to us. Accordingly,
these statements are subject to certain risks, uncertainties, and contingencies,
which could cause our actual results, performance, or achievements to differ
materially from those expressed in, or implied by, such statements. These risks,
uncertainties and contingencies include, without limitation, the factors set
forth in our Form 10-KSB under "Item 6. Management's Discussion and Analysis of
Financial Conditions or Plan of Operation - Factors that may affect future
operating results." We have no obligation to update or revise any such
forward-looking statements that may be made to reflect events or circumstances
after the date of this Form 10-QSB.

Liquidity and Capital Resources

March 31, 2002 as compared to March 31, 2001

At March 31, 2002 current assets were $1,579,675 and current liabilities were
$229,995 and we had positive working capital of $1,349,680 compared to current
assets of $3,303,463 at June 30, 2001 and current liabilities of $1,480,947 at
the same date, resulting in working capital at June 30, 2001 of $1,822,516. Our
current assets decreased by 52%, while current liabilities decreased by 84% from
June 30, 2001 to March 31, 2002 for several reasons.

     Our current assets decreased primarily because cash and cash equivalents
     decreased from approximately $2.7 million to approximately $1.3 million.
     Accounts receivable - trade decreased by about 56% because of the lower
     prices received for oil and gas production, and decreased production
     volumes experienced during the nine months ended March 31, 2002.

     Our current liabilities decreased to $230,000 at March 31, 2002, from
     approximately $1.5 million at June 30, 2001. This reduction was due to a
     number of factors, including a decrease in accounts payable of $963,000 due
     to a decrease in drilling activity caused by the completion of planned
     drilling projects, a decrease of $287,000 in advance payments received from
     joint owners also caused by project completions at March 31, 2002.

We anticipate that our current assets will be sufficient to pay our current
liabilities as long as our oil and gas production continues to provide us with
sufficient cash flow. As discussed below, this is dependent, in part, on
maintaining or increasing our level of production and the national and world
market maintaining its current prices for our oil and gas production.


During the nine month period ending March 31, 2002, we experienced a sharp
decline in production and prices received for the natural gas we produced during
that period. At June 30, 2001, we received an average of $10.16 per MMBTU. At
March 31, 2002 our price per MMBTU had been reduced to approximately $2.38 per
MMBTU, a 77% decline. During the month of April 2002 we will receive an average
price of $3.30 per MMBTU, a 39% improvement, but substantially below year ago
prices which averaged $8.87 per MMBTU.

In conjunction with a decline in prices we have also experienced a decline in
production volumes for the period. For the nine months ended March 31, 2002 we
produced approximately 293,000 MMBTU of gas compared to approximately 171,000
MMBTU for the nine months ended March 31, 2002, a 41% decline.

Our capital requirements can fluctuate over a twelve month period because our
drilling program is usually carried out in California's dry season, from late
April until November, after which wet weather either precludes further activity
or makes it cost prohibitive.

Although our drilling and development plans have not been finalized for the
coming year, at March 31, 2002 we have spudded one well and are committed to
drill 2 additional wells at an estimated dry hole cost to us of approximately
$162,000, with the balance (approximately $850,000) to be paid by joint owners
in the properties, including certain affiliated investors. For the nine months
ended March 31, 2002 we invested $600,000 in our oil and gas properties compared
to approximately $420,000 for the nine month period in the preceding fiscal
year. We anticipate additional drilling will occur in fiscal 2002.

We believe that internally generated funds will be sufficient to finance our
drilling and operating expenses for the next twelve months.


We believe the following critical accounting policies affect our most
significant judgments and estimates used in the preparation of our Consolidated
Financial Statements.

Reserve Estimates: Our estimates of oil and natural gas reserves, by necessity,
are projections based on geologic and engineering data, and there are
uncertainties inherent in the interpretation of such data as well as the
projection of future rates of production and the timing of development
expenditures. Reserve engineering is a subjective process of estimating
underground accumulations of oil and natural gas that are difficult to measure.
The accuracy of any reserve estimate is a function of the quality of available
data, engineering and geological interpretation and judgment. Estimates of
economically recoverable oil and natural gas reserves and future net cash flows
necessarily depend upon a number of variable factors and assumptions, such as
historical production from the area compared with production from other
producing areas, the assumed effects of regulations by governmental agencies and
assumptions governing future oil and natural gas prices, future operating costs,
severance and excise taxes, development costs and workover and remedial costs,
all of which may in fact vary considerably from actual results. For these
reasons, estimates of the economically recoverable quantities of oil and natural
gas attributable to any particular group of properties, classifications of such
reserves based on risk of recovery, and estimates of the future net cash flows
expected there from may vary substantially. Any significant variance in the
assumptions could materially affect the estimated quantity and value of the
reserves, which could affect the carrying value of our oil and gas properties
and/or the rate of depletion of the oil and gas properties. Actual production,
revenues and expenditures with respect to our reserves will likely vary from
estimates, and such variances may be material.


Many factors will affect actual future net cash flows, including:

     -    the amount and timing of actual production;
     -    supply and demand for natural gas;
     -    curtailments or increases in consumption by natural gas purchasers;
     -    changes in governmental regulations or taxation.

Property, Equipment and Depreciation: We follow the full-cost method of
accounting for oil and gas properties. Under this method, all productive and
nonproductive costs incurred in connection with the exploration for and
development of oil and gas reserves are capitalized. Such capitalized costs
include lease acquisition, geological and geophysical work, delay rentals,
drilling, completing and equipping oil and gas wells, including salaries,
benefits and other internal salary related costs directly attributable to these
activities. Costs associated with production and general corporate activities
are expensed in the period incurred. Interest costs related to unproved
properties and properties under development are also capitalized to oil and gas
properties. If the net investment in oil and gas properties exceeds an amount
equal to the sum of (1) the standardized measure of discounted future net cash
flows from proved reserves, and (2) the lower of cost or fair market value of
properties in process of development and unexplored acreage, the excess is
charged to expense as additional depletion. Normal dispositions of oil and gas
properties are accounted for as adjustments of capitalized costs, with no gain
or loss recognized.

We apply SFAS No. 121, "Accounting for the Impairment of Long-Lived Assets and
for Long-Lived Assets to be Disposed of." Under SFAS No. 121, long-lived assets
and certain intangibles are reported at the lower of the carrying amount or
their estimated recoverable amounts. Long-lived assets subject to the
requirements of SFAS No. 121 are evaluated for possible impairment through
review of undiscounted expected future cash flows. If the sum of undiscounted
expected future cash flows is less than the carrying amount of the asset or if
changes in facts and circumstances indicate, an impairment loss is recognized.


We had contractual obligations as of March 31, 2002. The following table lists
our significant liabilities at March 31, 2002:

                                             Payments Due By Period
                             Less than                         After
  Contractual Obligations    1 year    2-3 years   4-5 years   5 years   Total
  -----------------------    ------    ---------   ---------   -------   -----

  Operating leases           $26,300   $52,600     $52,600     $ -0-    $131,500
                             --------  ---------   ---------   -----    --------

  Total contractual
    cash obligations         $26,300   $52,600     $52,600     $ -0-    $131,500
                             ========  =========   =========   =====    ========

We lease corporate offices in Denver, Colorado with support offices in Castle
Rock, Colorado and Bakersfield, California. The Denver office lease expires
December 31, 2002, the Bakersfield office lease expires February 28, 2003 and
the Castle Rock office is leased on a month to month basis. Combined yearly
lease payments are approximately $26,300.

In addition to office leases, we are responsible for various compressor rentals
located on our California producing properties. These leases are on a month to
month basis and total approximately $21,500 per year.


Results of Operations

March 31, 2002 Compared to March 31, 2001

For the nine months ended March 31, 2002 our operations continued to be focused
on the production of oil and gas, and the investigation for possible acquisition
of producing oil and gas properties in California.

Oil and gas revenues, which includes income from management fees, for the nine
months ended March 31, 2002 decreased approximately $2,195,000 from $2,800,000
to $605,000, a 78% decrease. This decrease reflects an erosion of prices and
reduced production volumes in California. Our share of sales of oil and gas for
the nine month period ended March 31, 2002 were 2410 barrels of oil and
approximately 171,000 MMBTU of gas with the price received for oil at $19.32 per
barrel and $2.70 per MMBTU for gas. This is a decrease in total oil production
compared to the 4028 barrels of oil produced in the nine months ended March 31,
2001, and a decrease in natural gas production of 122,000 MMBTU when compared to
the approximately 293,000 MMBTU of gas production achieved during the nine
months ended March 31, 2001. As discussed in Liquidity and Capital Revenues, a
significant factor resulting in the substantial decrease in revenues during the
last nine months of fiscal 2002 was a decrease in the prices received for our
production when compared to prices of $26.90 and $8.87 received for oil and gas
respectively during the first nine months of fiscal 2002.

Oil and gas production costs decreased $48,897 when compared to the last nine
month period, from $151,585 to $102,688. Production costs decreased
approximately $62,000 due to the elimination of non-recurring workover costs for
recompleting wells in upper producing zones. Production costs increased
approximately $13,000 because of the addition of new wells and compression costs
associated with older producing wells, as well as increased water production and
workover costs associated with two oil wells which were sold during the third
quarter of 2002.

Depletion, depreciation and amortization increased $128,000 or 58% for the nine
month period, which is our best estimate of what the full year cost will be.

Selling, general and administrative expense increased approximately 5% from
$449,800 to $471,725 for the nine months ended March 31, 2002. This increase is
primarily due to salary and office rental increases, and was offset by the
receipt of approximately $10,000 from Aspen Power Systems for the services of
our president R. V. Bailey.

As a result of our operations for the nine months ended March 31, 2002, we ended
the period with a net loss of $226,600 after taxes compared to net income of
$1,908,000 for the year earlier. This loss of approximately $226,600 is due to a
decrease in production and the price received for our oil and gas as discussed
earlier as well as the fact that our depletion costs rose substantially during
the nine month period ending March 31, 2002.

Interest and other income decreased approximately $26,000 to $46,600 and is due
to our maintaining a lower average balance of funds in our invested cash
accounts, thereby reducing our interest income by $11,900, and a decrease in
funds received from Aspen Power Systems of $12,800 from $23,200 to $10,400.


In accordance with the requirements of the Securities Exchange Act of 1934, we
have duly caused this report to be signed on our behalf by the undersigned,
thereunto duly authorized.

                                        ASPEN EXPLORATION CORPORATION

                                        /s/ R. V. Bailey
                                        By: R. V. Bailey,
May 10, 2002                            Chief Executive Officer,
                                        Principal Financial Officer