FORM 10QSB/A-1
SECURITIES AND EXCHANGE COMMISSION
Washington D.C. 20549
MARK ONE
[ X ] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2000
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ________ to ________
Commission File Number 09494
ASPEN EXPLORATION CORPORATION
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(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
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(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 November 9, 2000
----- -------------------------------
Common stock, $.005 par value 5,345,938
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Part One. FINANCIAL INFORMATION
Item 1. Financial Statements
ASPEN EXPLORATION CORPORATION AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, June 30,
2000 2000
----------- -----------
(Unaudited) (Audited)
Current Assets:
<S> <C> <C>
Cash and cash equivalents, including $2,055,200 and
$417,443 of invested cash at September 30, 2000 and
June 30, 2000 respectively.................................... $ 2,302,667 $ 507,382
Precious metals............................................... 18,823 18,823
Accounts receivable, trade.................................... 526,832 340,177
Prepaid expenses.............................................. 17,430 9,259
----------- -----------
Total current assets..................................... 2,865,752 875,641
----------- -----------
Investment in oil and gas properties, at cost
(full cost method of accounting).............................. 3,071,819 2,942,712
Less accumulated depletion and valuation allowance............ (1,580,589) (1,520,589)
----------- -----------
1,491,230 1,422,123
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Property and equipment, at cost:
Furniture, fixtures and vehicles.............................. 201,654 201,654
Less accumulated depreciation................................. (132,689) (128,689)
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68,965 72,965
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Cash surrender value, life insurance.......................... 239,095 239,095
----------- -----------
TOTAL ASSETS............................................. $ 4,665,042 $ 2,609,824
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(Statement Continues)
See notes to Consolidated Financial Statements
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ASPEN EXPLORATION CORPORATION AND SUBSIDIARY
CONSOLIDATED BALANCE SHEETS (Continued)
LIABILITIES AND STOCKHOLDERS' EQUITY
September 30, June 30,
2000 2000
----------- -----------
(Unaudited) (Audited)
Current liabilities:
Accounts payable and accrued expense.............. $ 1,558,448 $ 363,955
Advances from joint owners........................ 713,534 169,713
Income taxes payable.............................. 19,400 23,000
Notes payable - current........................... 224,180 236,746
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Total current liabilities......................... 2,515,562 793,414
----------- -----------
Stockholders' equity:
Common stock, $.005 par value:
Authorized: 50,000,000 shares
Issued: At September 30, 2000: 5,345,938
and June 30, 2000: 5,345,938.................. 26,729 26,729
Capital in excess of par value.................... 6,017,610 6,017,610
Accumulated deficit............................... (3,862,426) (4,191,096)
Deferred compensation............................. (32,433) (36,833)
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Total stockholders' equity........................ 2,149,480 1,816,410
----------- -----------
Total liabilities and stockholders' equity........ $ 4,665,042 $ 2,609,824
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See Notes to Consolidated Financial Statements
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ASPEN EXPLORATION CORPORATION AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
Three Months Ended
September 30,
------------------------
(unaudited)
2000 1999
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Revenues:
Oil and gas....................................... $ 561,694 $ 273,274
Management fees................................... 56,032 17,566
Interest and other, net........................... 10,121 2,085
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Total Revenues...................................... 627,847 292,925
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Costs and expenses:
Oil and gas production............................ 57,542 14,854
Depreciation, depletion and amortization.......... 64,000 59,925
Aspen Power Systems expense....................... 0 21,209
Selling, general and administrative............... 151,295 139,542
Interest expense.................................. 6,940 3,498
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Total Costs and Expenses............................ 279,777 239,028
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Net income before taxes............................. $ 348,070 $ 53,897
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Provision for income taxes.......................... 19,400 0
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Net income.......................................... $ 328,670 $ 53,897
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Basic earnings per common share..................... $ .06 $ .01
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Diluted earnings per common share................... $ .06 $ .01
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Basic weighted average number of common shares
outstanding........................................ 5,345,938 5,191,322
========== ==========
Diluted weighted average number of common shares
outstanding......................................... 5,693,138 5,348,389
========== ==========
The accompanying notes are an integral
part of these statements.
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<CAPTION>
ASPEN EXPLORATION CORPORATION AND SUBSIDIARY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
Three months ended September 30,
2000 1999
------------------
Cash flows from operating activities:
-------------------------------------
<S> <C> <C>
Net income.......................................... $ 328,670 $ 53,897
Adjustments to reconcile net income
to net cash provided by
operating activities:
Depreciation, depletion & amortization............ 64,000 59,925
Amortization of deferred compensation............. 4,400 --
Changes in assets and liabilities:
Increase in accounts receivable................... (186,655) (187,826)
(Increase) decrease in prepaid expense............ (8,171) 3,838
Increase in accounts payable and accrued expense.. 1,734,714 701,577
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Net cash provided by operating activities......... 1,936,958 631,411
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Cash flows from investing activities:
-------------------------------------
Additions to oil & gas properties................. (129,107) (24,862)
Purchase of office equipment...................... -- (3,700)
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Net cash used in investing activities............. (129,107) (28,562)
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Cash flows from financing activities:
-------------------------------------
Repayment of notes payable........................ (12,566) (13,828)
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Net cash used in financing activities............. (12,566) (13,828)
Net increase in cash and cash equivalents......... 1,795,285 589,021
Cash and cash equivalents, beginning of year...... 507,382 335,603
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Cash and cash equivalents, end of year............ $ 2,302,667 $ 924,624
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Interest paid..................................... $ 6,940 $ 3,498
=========== ===========
Income taxes paid................................. $ 8,000 $ 0
=========== ===========
The accompanying notes are an integral
part of these statements.
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ASPEN EXPLORATION CORPORATION
Notes to Consolidated Financial Statements
(Unaudited)
September 30, 2000
Note 1 BASIS OF PRESENTATION
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 10KSB for the year ended June
30, 2000.
Except for the historical information contained in this Form 10QSB, this
Form contains forwardlooking 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 10KSB for the year ended June 30, 2000.
Note 2 EARNINGS PER SHARE
In February 1997, the Financial Accounting Standards Board issued Financial
Accounting Standard 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.
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Note 2 EARNINGS PER SHARE (CONTINUED)
The following is a reconciliation of the numerators and denominators used
in the calculations of basic and diluted earnings per share for the three
months ended September 30, 2000 and 1999:
September 30, 2000 September 30, 1999
------------------------------ ---------------------------
Per Per
Net Share Net Share
Income Shares Amount Income Shares Amount
------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C>
Basic earnings per share:
Net income and
share amounts 328,670 5,345,938 .06 53,897 5,191,322 .01
Dilutive securities
stock options 680,000 460,000
Repurchased shares (332,800) (302,933)
--------------------------------------------------------------
Diluted earnings per share:
Net income and assumed
share conversion 328,670 5,693,138 .06 53,897 5,348,389 .01
======= ========= === ====== ========= ===
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Note 3 SEGMENT INFORMATION
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 131). The adoption of SFAS 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.
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Note 3 SEGMENT INFORMATION (CONTINUED)
During the three months ended September 30, 2000 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 capitalized approximately $129,000 for the
development and acquisition of oil and gas properties.
Segment information consists of the following for the three months ended
September 30:
Oil and Gas Corporate Consolidated
----------- --------- ------------
Revenues:
2000 $ 617,726 $ 10,121 $ 627,847
1999 290,840 2,085 292,925
Income (loss) from operations:
2000 $ 480,784 $ (152,114) $ 328,670
1999 219,986 (166,089) 53,897
Identifiable assets:
2000 $ 2,018,062 $ 2,646,980 $ 4,665,042
1999 1,294,862 1,230,415 2,525,277
Depreciation, depletion and
valuation charged to
identifiable assets:
2000 $(1,580,589) $ (132,689) $(1,713,278)
1999 (1,336,305) (140,162) (1,476,467)
Capital expenditures:
2000 $ 129,107 $ 0 $ 129,107
1999 24,862 3,700 28,562
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Note 4 MAJOR CUSTOMERS
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:
September 30, 2000 -- 17% 11% 65%
September 30, 1999 75% -- -- --
Note 5 NOTES PAYABLE
We owe the following debt:
September 30, June 30,
2000 2000
-------------------------------
Borrowings from life insurance company
on cash surrender value of officer life
insurance, interest at 6% per annum,
collateralized by cash surrender value
of policy. $155,430 $155,430
Note payable to related party,
Interest at 11.21% per annum,
monthly principal and interest
payments of $4,269, due September,
2000, collateralized by working
interests in the Emigh lease. $ 0 12,566
Note payable to third party for
the acquisition purchase of
producing oil and gas properties.
Interest at 5.475% per annum.
Principal payments of $68,875 are
due in January 2001. There is no
collateral for this note. 68,750 68,750
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Total notes payable 224,180 236,746
Less current portion 224,180 236,746
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Long term portion $ 0 $ 0
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Note 6 COMMITMENTS AND CONTINGENCIES
At September 30, 2000 the Company was committed to the following drilling
and development projects in California:
1. Drill, complete and equip the Emigh 35-3 well.
2. Drill, complete and equip the Wineroth 24-1 well.
3. Drill, complete and equip the Emigh 35-4 well.
4. Drill, complete and equip the Brick House 1-9.
Total costs for the Emigh 35-3 well are estimated to be $820,000 of which
$75,600 will be paid by us. As of September 30, 2000 we have received
$702,000 from third party investors for their share of the well costs. We
are currently completing this well as a producing gas well.
The Wineroth 24-1 well was spudded on November 3, 2000 and was plugged and
abandoned on November 6, 2000. We estimate the total well costs to be
approximately $300,000 with our share of the costs approximately $6,000. At
September 30, 2000 we had received no funds from third party investors.
The Emigh 35-4 well was spudded on October 29, 2000 and is currently being
drilled. Continental Operating Company is the operator of this well and our
share of the costs of this well is estimated to be $46,000.
Total costs of the Brick House 1-9 well are estimated to be $525,000 with
our share of the net costs approximately $44,000. As of this filing we have
not begun drilling this well.
Note 7 SUBSEQUENT EVENTS
On October 5, 2000 we paid in full our outstanding loan balance of $155,430
plus $5,051 in accrued interest to the Security Life Insurance Company.
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Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
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 10KSB for the year ended June 30, 2000, which has been
filed with the Securities and Exchange Commission. This management's discussion
and analysis and other portions of this report contain forwardlooking 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
forwardlooking 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 forwardlooking
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 10KSB 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
forwardlooking statements that may be made to reflect events or circumstances
after the date of this Form 10QSB.
Liquidity and Capital Resources
-------------------------------
September 30, 2000 as compared to September 30, 1999
----------------------------------------------------
At September 30, 2000 current assets were $2,865,752 and current liabilities
were $2,515,562 and we had positive working capital of $350,190 compared to
current assets of $875,641 at June 30, 2000 and current liabilities of $793,414
at the same date, resulting in working capital at June 30, 2000 of $82,127. Our
current assets and liabilities increased more than threefold from June 30, 2000
to September 30, 2000 for several reasons.
Our current assets increased primarily because cash and cash equivalents
increased from approximately $508,000 to approximately $2.3 million. Much
of this increase was due to advances paid to us from joint working interest
owners for the drilling of wells, principally $702,000 relating to the
anticipated drilling of the Emigh 353 well. Accounts receivable - trade
also increased by about 50% because of the higher prices being received for
oil and gas production, and funds received from oil and gas sales not
disbursed to joint owners at September 30, 2000.
Our current liabilities increased to $1.7 million at September 30, 2000,
approximately three times the $793,000 amount at June 30, 2000. This
increase was due primarily to a number of factors, including an increase in
accounts payable of $120,000 due to increased drilling activity, an
increase of $540,000 in advance payments received from joint owners but not
expended for drilling activities at September 30, 2000 and $1,060,000 in
oil and gas revenue due joint owners not distributed until October 2000.
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Another component of our current liabilities, advances from joint owners,
increased significantly from June 30, 2000 ($170,000) to September 30, 2000
($714,000) primarily because of the funds we received for the drilling of
the Emigh 353 well.
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.
In light of recent successful drilling operations, the acquisition of producing
properties and the continued improvement in oil and gas prices received by us,
increased revenues should continue to have a positive effect on our working
capital and contribute significantly to its cash flow in the year ahead.
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.
In order to provide interim financing, we borrowed $130,000 during 1997 from an
affiliate to finance our share of drilling an offset well on the Denverton Creek
property. In April 2000 we withdrew $125,000 against a split dollar life
insurance plan to facilitate the payment of our drilling obligations. The
affiliate loan was paid in full during August 2000, and the split dollar life
insurance loan was subsequently paid in full during October 2000.
Although our drilling and development plans have not been finalized for the
coming year, at September 30, 2000 we are committed to drill four additional
wells at an estimated cost to us of approximately $171,000, with the balance
(approximately $2,520,000) to be paid by joint owners in the properties,
including certain affiliated investors. For the three months ended September 30,
2000 we invested $129,000 in our oil and gas properties compared to
approximately $25,000 for the three month period in the preceding fiscal year.
We anticipate additional drilling will occur in fiscal 2001.
We believe that internally generated funds will be sufficient to finance our
drilling and operating expenses for the next twelve months.
While we have substantially reduced our outstanding debt at this writing, we may
be required again to seek outside funding to facilitate our 2001 drilling
program.
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Results of Operations
---------------------
September 30, 2000 Compared to September 30, 1999
-------------------------------------------------
For the three months ended September 30, 2000 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 three
months ended September 30, 2000 increased approximately $327,000 from $290,840
to $617,726, a 112% increase. This increase reflects our continued emphasis on
operations conducted in California and increased production from both the
Denverton Creek and Malton Black Butte fields even though our production overall
decreased. Our share of sales of oil and gas for the three month period ended
September 30, 2000 were 1300 barrels and oil and approximately 105,000 MMBTU of
gas with the price received for oil at $28.84 per barrel and $4.99 per MMBTU for
gas. This is a decrease in total oil production compared to the 1873 barrels of
oil produced in the first quarter of fiscal 2000, and an increase in natural gas
production when compared to the approximately 85,600 MMBTU of gas when compared
to the production achieved during the first quarter of the 2000 fiscal year. A
significant factor resulting in the substantially increased revenues during the
first quarter of fiscal 2000 was an increase in the prices received for our
production when compared to prices of $18.60 and $2.75 received for oil and gas
respectively during the first quarter of fiscal 2000.
Oil and gas production costs increased $42,688 when compared to last quarter
from $14,854 to $57,542. Approximately $30,000 of this increase was due to
nonrecurring workover costs for recompleting wells in upper producing zones, the
balance, approximately $13,000 reflects the addition of new wells and
compression costs associated with older producing gas wells.
Depletion, depreciation and amortization increased $4,075 or 7% from the
previous quarter, which is our best estimate of what the full year cost will be.
Selling, general and administrative expense increased approximately 8% from
$139,542 to $151,295 for the quarter ended September 30, 2000. This increase is
primarily due to salary and office rental increases and the amortization of
deferred officer compensation costs of $4,400.
As a result of our operations for the three months ended September 30, 2000, we
ended the quarter with net income of $328,670 after taxes compared to $53,897
for the year earlier. This increase of approximately $275,000 is due to an
increase in production and the price received for our oil and gas as discussed
earlier as well as the fact that our costs of production did not increase as
quickly as the prices received for our production.
Interest and other income increased approximately $8,000 to $10,121 and is due
to our maintaining a greater balance of funds in our invested cash accounts.
With Management's continued emphasis on cost control, successful drilling and
production operations and its improving gas sales, we believe our net income and
earnings per share will continue to grow, assuming oil and gas prices maintain
their current level or increase.
13
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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
By: /s/ R. V. Bailey
----------------------------------
R. V. Bailey,
November 9, 2000 Chief Executive Officer,
Principal Financial Officer
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