UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
For the quarterly period ended June 30, 1997
OR
[ ] TRANSACTION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from ______________________ to _________________
Commission File Number 0-9946
GOLDEN OIL COMPANY
(Exact name of registrant as specified in its charter)
Delaware 84-0836562
(State or other jurisdiction (I.R.S. Employer Identification No.)
of incorporation or organization)
550 Post Oak Boulevard, Suite 550, Houston, Texas 77027
(Address of principal executive offices) (Zip Code)
(713) 622-8492
(Registrants telephone number, including area code)
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 [ ] NO [X]
As of August 1, 1997, the Registrant had outstanding 1,424,291 shares of
common stock, par value $.01 per share and 22,254 shares of Class B common
stock, par value $.01 per share.
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CONTENTS
Page
----
PART I. FINANCIAL INFORMATION
Item 1. Financial Statements
- Consolidated Statements of Operations.................... 3
- Consolidated Balance Sheets.............................. 5
- Consolidated Statements of Cash Flows.................... 7
- Notes to Consolidated Financial Statements............... 9
Item 2. Management's Discussion and Analysis of
Financial Condition and Results of Operations................ 16
PART II. OTHER INFORMATION
Item 6. Exhibits and Reports on Form 8-K............................. 23
Page 2 of 24
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GOLDEN OIL COMPANY
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
THREE MONTHS ENDED
JUNE 30,
----------------------------
1997 1996
----------- -----------
Revenues:
Oil and gas production .................... $ 456,344 $ 316,912
Other ..................................... 6,886 7,707
----------- -----------
Total revenues ......................... 463,230 324,619
----------- -----------
Costs and expenses:
Production costs .......................... 318,146 200,694
Depreciation, depletion and
amortization ............................ 79,343 99,810
General and administrative ................ 99,376 82,299
----------- -----------
Total costs and expenses ............... 496,865 382,803
----------- -----------
(33,635) (58,184)
Gain (loss) on sale of property,
equipment and other assets ................ (7,552) --
Interest expense, net ........................ (4,567) (6,069)
Other income (expense) ....................... (1,220) (4,898)
----------- -----------
Net earnings (loss) .......................... $ (46,974) $ (69,151)
=========== ===========
Net earnings (loss) per common share ......... $ (.03) $ (.05)
=========== ===========
Weighted average number of
common shares and common
share equivalents outstanding ............. 1,424,291 1,424,291
=========== ===========
See Notes to Consolidated Financial Statements.
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GOLDEN OIL COMPANY
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
SIX MONTHS ENDED
JUNE 30,
---------------------------
1997 1996
----------- -----------
Revenues:
Oil and gas production ...................... $ 878,708 $ 594,569
Other ....................................... 13,222 14,713
----------- -----------
Total revenues ........................... 891,930 609,282
----------- -----------
Costs and expenses:
Production costs ............................ 624,722 393,165
Depreciation, depletion and
amortization .............................. 160,906 201,966
General and administrative .................. 165,084 132,141
----------- -----------
Total costs and expenses ................. 950,712 727,272
----------- -----------
(58,782) (117,990)
Gain (loss) on sale of property,
equipment and other assets .................. (7,552) --
Interest expense, net .......................... (9,643) (10,620)
Other income (expense) ......................... (1,590) (7,364)
----------- -----------
Net earnings (loss) before cumulative
effect of accounting change ................. (77,567) (135,974)
Cumulative effect of accounting
change (Note 1) ............................. -- (39,770)
----------- -----------
Net earnings (loss) ............................ $ (77,567) $ (175,744)
=========== ===========
Per share data:
Net earnings (loss) before
cumulative effect of accounting change ... (.05) (.09)
Cumulative effect of accounting change ...... -- (.03)
----------- -----------
Net earnings (loss) per common share ........ $ (.05) $ (.12)
=========== ===========
Weighted average number of
common shares and common
share equivalents outstanding ............... 1,424,291 1,424,291
=========== ===========
See Notes to Consolidated Financial Statements.
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GOLDEN OIL COMPANY
CONSOLIDATED BALANCE SHEETS
(UNAUDITED)
JUNE 30, DECEMBER 31,
1997 1996
----------- -----------
ASSETS
Current assets:
Cash and cash equivalents ................ $ 138,440 $ 165,209
Short-term investments ................... 25,753 25,000
Accounts receivable, net ................. 290,520 370,136
Prepaid expenses and other ............... 29,363 35,997
----------- -----------
Total current assets ................ 484,076 596,342
----------- -----------
Property and equipment, at cost:
Oil and gas properties
(using the successful efforts
method of accounting)
Producing properties ................ 5,855,159 5,781,349
Non-producing properties ............ 105,000 105,000
----------- -----------
Total oil and gas properties ........ 5,960,159 5,886,349
----------- -----------
Pipeline, field and other well
equipment ................................ 233,858 242,902
Other property and equipment ................. 450,791 468,911
----------- -----------
6,644,808 6,598,162
Less accumulated depreciation,
depletion and amortization ............... (3,705,777) (3,566,746)
----------- -----------
Net property and equipment ............... 2,939,031 3,031,416
----------- -----------
Investments, real estate ..................... 193,709 196,234
Other assets ................................. 1,481 1,481
----------- -----------
$ 3,618,297 $ 3,825,473
=========== ===========
(Continued)
See Notes to Consolidated Financial Statements.
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GOLDEN OIL COMPANY
CONSOLIDATED BALANCE SHEETS (CONTINUED)
(UNAUDITED)
JUNE 30, DECEMBER 31,
1997 1996
------------ ------------
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Notes payable and
current portion of long-term debt ......... $ 108,600 $ 130,546
Accounts payable ............................ 1,154,131 1,322,896
Accrued expenses ............................ 108,986 131,496
------------ ------------
Total current liabilities .............. 1,371,717 1,584,938
------------ ------------
Long-term debt ................................. 82,980 69,383
Other liabilities .............................. 155,238 85,223
Commitments and contingencies
(See also Notes 4 and 5) ....................... -- --
Stockholders' equity:
Preferred stock, par value $.01;
authorized 10,000,000 shares, none issued
Common stock, par value $.01 authorized
15,000,000 shares, issued and
outstanding 1,424,291 shares at
June 30, 1997 and December 31, 1996 ........ 14,243 14,243
Class B common stock, par value $.01;
(convertible share for share into common
stock) authorized 3,500,000 shares, issued
and outstanding 22,254 shares at
June 30, 1997 and December 31, 1996 ........ 223 223
Additional paid-in capital ..................... 13,864,479 13,864,479
Accumulated deficit ............................ (11,870,583) (11,793,016)
------------ ------------
Total stockholders' equity ............. 2,008,362 2,085,929
------------ ------------
$ 3,618,297 $ 3,825,473
============ ============
See Notes to Consolidated Financial Statements.
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GOLDEN OIL COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
SIX MONTHS ENDED
JUNE 30,
------------------------
1997 1996
--------- ---------
Cash flows from operating activities:
Net earnings (loss) ........................... $ (77,567) $(175,744)
Adjustments to reconcile net
income to net cash provided
by operating activities:
Depreciation, depletion
and amortization ........................... 160,906 201,966
Equity in net loss of
investment in commercial realty ............ 2,526 9,754
(Gain) loss on sale of property
and equipment .............................. 7,552 --
Cumulative effect of accounting
change ..................................... -- 39,770
Changes in components of working capital:
(Increase) decrease in accounts
receivable, net ......................... 79,616 30,146
(Increase) decrease in prepaid
expenses and other ...................... 6,634 (4,082)
Increase (decrease) in accounts
payable ................................. (168,765) (94,928)
Increase (decrease) in accrued
expenses ................................ (22,510) (16,452)
Increase (decrease) in
other liabilities ....................... 70,015 --
--------- ---------
Net cash provided by (used
in) operating activities .................. $ 58,407 $ (9,570)
--------- ---------
(Continued)
See Notes to Consolidated Financial Statements.
Page 7 of 24
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GOLDEN OIL COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS (CONTINUED)
(UNAUDITED)
SIX MONTHS ENDED
JUNE 30,
------------------------
1997 1996
--------- --------
Cash flows from investing activities:
Proceeds from sale of property
and equipment .............................. $ 1,803 $ --
Additions of oil and gas properties .......... (73,810) (54,227)
Additions of other property and
equipment ................................. (4,067) (562)
Increase in short-term investments ........... (753) --
--------- --------
Net cash used in investing activities ........... $ (76,827) $(54,789)
--------- --------
Cash flows from financing activities:
Proceeds from issuance of
long-term debt ............................. 64,566 67,811
Payment of long-term debt .................... (72,915) (55,038)
--------- --------
Net cash provided by (used in)
financing activities ......................... $ (8,349) $ 12,773
--------- --------
Net increase (decrease) in cash and
cash equivalents ............................. (26,769) (51,586)
Cash and cash equivalents at
beginning of period .......................... 165,209 67,599
--------- --------
Cash and cash equivalents at
end of period ................................ $ 138,440 $ 16,013
========= ========
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid for interest expense was $10,304 and $12,498 for the six months
ended June 30, 1997 and 1996, respectively. No cash was paid for income taxes
during the same corresponding periods.
See Notes to Consolidated Financial Statements
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GOLDEN OIL COMPANY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) SUMMARY OF SIGNIFICANT ACCOUNTING PRINCIPLES
For a summary of significant accounting principles, see Notes to
Consolidated Financial Statements and Note 1 thereof contained in the
Annual Report on Form 10-K of Golden Oil Company ("Golden" or "Company")
for the year ended December 31, 1996. The Company follows the same
accounting policies during interim periods as it does for annual reporting
purposes.
The accompanying consolidated financial statements are condensed and
unaudited and have been prepared pursuant to the rules and regulations of
the Securities and Exchange Commission ("SEC"). In the opinion of
management, the unaudited interim financial statements reflect such
adjustments as are necessary to present a fair statement of the financial
position, results of operations and cash flows for the interim periods
presented. Interim results are not necessarily indicative of a full year
of operations. Certain information and note disclosures normally included
in annual financial statements prepared in accordance with generally
accepted accounting principles have been condensed or omitted pursuant to
SEC rules and regulations; however, the Company believes that the
disclosures made are adequate to make the information presented not
misleading. These financial statements should be read in conjunction with
the financial statements and the notes thereto included in the Company's
Form 10-K for the year ended December 31, 1996.
Page 9 of 24
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RECLASSIFICATIONS
Certain amounts from prior periods have been reclassified to conform
to the presentation format for the 1997 Consolidated Financial Statements
with no effect on reported results of operations.
ACCOUNTS RECEIVABLE
Amounts shown as accounts receivable are net of $91,718 at June 30,
1997 and December 31, 1996 to reflect estimated provisions for doubtful
collection of certain non-recourse obligations primarily in connection
with certain working interest participants and drilling arrangements of a
Company subsidiary. Accounts receivable reflect net amounts due from
affiliates of $31,915 at June 30, 1997 and $55,803 at December 31, 1996.
INVESTMENTS
The Company's short-term investments at June 30, 1997 and December
31, 1996 consisted of a certificate of deposit held by a federally insured
bank. Certificates of deposit are held until maturity and, accordingly,
are carried at cost.
The Company holds a limited partnership interest in its headquarters
office building. The Company accounts for this investment using the equity
method and, accordingly, the Company recognizes its pro-rata share of net
income or loss of the limited partnership in its current operating
statements.
ACCOUNTING CHANGE
Effective January 1, 1996 the Company changed its depletion method
on producing oil and gas properties from the property-by-property basis to
the field basis of applying the unit-of-production method. The field basis
provides for the aggregation of wells that have a common geological
reservoir or field. The Company believes the field basis provides a better
matching of expenses with revenues over the productive life of the
properties and, therefore, the Company believes the field basis method is
preferable to the property-by-property basis method. The cumulative
negative effect of this change in accounting method of $39,770 ($.03 per
share) is reported separately in the accompanying consolidated statements
of operations. At the date of the change in accounting method, the net
effect of the change was a $21,600 decrease in depletion and depreciation
expense and a $21,600 increase in net income ($.02 per share) reported for
the three months ended March 31, 1996.
(2) CERTAIN FIXED PRICE SALE AGREEMENTS
In order to plan Company operations and to provide protection
against sudden declines in oil and gas prices, from time to time the
Company enters into fixed price oil
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sales contracts. During the first six months of 1997 the Company
maintained fixed price arrangements for approximately 60% of its monthly
oil production. These arrangements extend through July 1997 at an average
wellhead price of approximately $22 per barrel. During July 1997, the
Company entered new fixed price arrangements for 40% of its anticipated
monthly oil volumes at a price of approximately $18.50 per barrel through
October 1997. The Company believes it has entered into these fixed price
arrangements with financially capable purchasers and does not anticipate
nonperformance by the counterparties to such transactions. In the event of
nonperformance by any of the counterparties, the Company believes that,
subject to future market prices, it will be able to market its production
to other parties under similar or then market value terms and conditions.
(3) DEVELOPMENT OF SOUTH DOG CREEK FIELD
In March 1993, an agreement was reached between the Company and
Calumet Oil Company, the principal operators in the South Dog Creek,
Oklahoma field, aimed at enhancing and extending the producing life of the
field by injection of water into the Mississippian formation in ten wells
covering four separate quarter section leases. The operators filed for a
water injection permit with the EPA, and during October 1993, a field-wide
water injection permit was granted by the EPA to the Company and another
interest holder and operator. During the fourth quarter of 1995 the
Company initiated a limited waterflood injection program on one of its
operated leases believed to have demonstrated engineering potential for
success. The program involves converting certain marginally producing
wells to water injectors and reworking producing wells and well equipment
to increase the wells' fluid volume capacity. The cost of the initial
phase of the waterflood project on this lease through June 1997 was
approximately $222,000, exclusive of operating fees charged by the
Company, of which the Company's share was approximately $164,000. The
Company funded its share of costs through internal cash flows with the
balance paid by outside working interest owners who elected to join the
project.
The Company is gradually increasing the rate and total volume of
water injected into the producing formation. Management will continue to
evaluate the results of current development before determining whether to
undertake additional development. The Company does not anticipate
significant increases in overall production volumes from the field unless
further development is implemented across a more extensive area and such
further development is successful. Currently, rates of injection have been
increased to a total of approximately 1,750 barrels of water per day into
three (3) injection wells. To date over 200,000 barrels of new water have
been injected into the producing formation; however, this volume is
estimated to be at least 400,000 barrels below the level at which
localized repressurization may be expected to occur. Based on indications
available from the localized response to water injection to date, the
Company plans to continue its injection program. If sufficient production
response is achieved, the Company will pursue a field-wide implementation
of its waterflood plan. Determination as to full scale, field-wide
development for water injection remains subject to, among other things,
engineering
Page 11 of 24
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advice based on the localized injection summarized above; projected oil
prices; and the availability of additional financing. At this time, due to
the variables discussed above, the Company is not able to provide a
definitive estimate of overall projected waterflood costs. As results are
received and analyzed, the Company will continue to review the historical
costs and the projected overall costs of the waterflood project. Subject
to the foregoing the Company is using a projection of $750,000, inclusive
of costs already incurred.
(4) ENVIRONMENTAL MATTERS
The Bureau of Land Management ("BLM") of the U.S. Department of the
Interior has implemented extensive national regulations for the handling
and maintenance of produced water from well sites on all federal lands.
The stated objective of the extensive new regulations is to provide
guidance for closure of unlined surface impoundments in a manner that
assures protection of fresh waters, public health and the environment. The
regulations require oil and gas companies to eliminate the use of unlined
surface impoundments in the operation of wells and to remediate and
replace them with lined and enclosed surface pits. Such new federal
government regulations provide for implementation on a region-by-region
basis.
During January 1997, the designated regions were expanded to include
approximately 80 wells in the Company's field of operations in New Mexico.
Pursuant to the Company's operating permit from the Jicarilla Apache
Indian Nation, the Company's operating subsidiary has been required to
develop a plan for remediation and improvement for every well site. During
May 1997 the BLM and the Jicarilla Environmental Protection Office ("EPO")
approved the initial phase of the plan submitted ("Plan"). The Plan
provided for the remediation and enclosure of 14 surface pits located at
the well sites by June 30, 1997 in accordance with applicable Ordinance
95-0-308-03. Surface pits on such well sites have been enclosed and soil
remediation is continuing in accordance with BLM and EPO regulations. Work
is ongoing for an additional fifteen well sites. Costs to date vary by
well site but have ranged between $1,500 to $5,000 per well site, or
approximately $55,000 in total, as to which the Company's pro-rata share
allocable to its working interest is approximately $28,000.
The required remediation on all well sites operated by the Company
in New Mexico is currently required to be completed by December 1998.
Numerous oil and gas producers in the region, including the Company, are
seeking extensions to such date but have not yet received such extension.
The total cost of such work is subject to a number of variable expense
factors including, among others, the cost and manner of disposal of
removed soil and the amounts of soil that may be required to be removed.
The Plan allows relatively broad soil disposal options; however, other
more costly soil disposal alternatives may be deemed necessary or may be
mandated by the regulatory agencies governing the remediation and
impoundment programs.
Based upon the preliminary information available at this time, the
Company has estimated the total cost to complete the entire remediation
and enclosure program in the
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Company's operating area to be in the range of approximately $200,000 to
$500,000. Total costs could vary significantly from the Company's estimate
due to the numerous variable factors discussed above. In recognition of
the above factors the Company has charged a provision reflecting its
preliminary estimate of its share of such costs of $75,000 to earnings in
the second quarter of 1997. The adequacy of such provision will be
reviewed by the Company as costs are better established, and such
provision may be increased in the future as required.
(5) INDEBTEDNESS
In April 1996, the Company entered into a new credit agreement with
a commercial bank in Albuquerque, New Mexico ("Bank") under which the
Company increased the borrowings available to it from $150,000 to
$400,000. In addition, the maturity schedule of the Company's debt was
extended to four years, subject to certain conditions. Such credit
facility was further required by the Bank to be independently, personally
guaranteed and to be collateralized by the Company's New Mexico oil and
gas properties.
Proceeds from the new credit facility have been utilized to
refinance short-term debt then outstanding; to acquire additional
interests in oil and gas properties offered to the Company by working
interest holders on leases in which the Company is operator; and to pay
other payables. At March 31, 1996 the Company had a working capital
deficit of approximately $1,000,000. In order to obtain the new financing
the Company was required by the lending Bank to provide a personal
guarantee from a principal officer of the Company for repayment in full to
the Bank of all principal, interest and related costs. As a result of its
financial position, the Company was not able to pay a cash fee for the
personal guarantee required by the Bank as a condition of extending credit
to the Company. In lieu of cash payment, the Company proposed to pay the
financing fee by delivering to the guarantor warrants to purchase
unregistered shares of its common stock. On March 29, 1996 the Board of
Directors approved execution by the Company of the credit agreement of the
Bank and the payment and delivery to the guarantor of warrants to purchase
250,000 unregistered shares of common stock of the Company through March
2006 for an exercise price of $.20 per share. As of March 28, 1997, the
guarantor had exercised rights to purchase 100,000 shares of common stock
granted under the warrants. At June 30, 1997, the shares had not been
issued by the Company and delivered by the Company's transfer agent.
Subsequent to June 30, 1997, such shares were issued. Accordingly, such
transaction will be reflected in the financial statements in the third
quarter of 1997.
Under the Company's new credit agreement, the Company is required to
make monthly payments of principal and interest, of approximately $10,400
through April 2000. As of August 14, 1997, the Company had borrowed
$341,000 and had $59,000 remaining available under the new credit
agreement.
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<PAGE>
The Company also maintained a credit facility in the original amount
of $100,000 with a commercial bank in Tulsa, Oklahoma and had borrowed
$70,000 under such line of credit facility. In March 1996, the Company
began reducing the principal amount borrowed under this credit facility by
$5,000 each month. Such line of credit was fully paid as of April 1997.
(6) PURCHASES OF OIL AND GAS INTERESTS
The Company's policy is to offer to purchase oil and gas interests
offered to it by holders within its area of operations. During 1996 and
1997 the Company purchased for approximately $65,000 and $50,000,
respectively, oil and gas interests in New Mexico. Such purchases
contributed additional gross revenues which favorably affected the
comparisons for the six months ended June 30, 1997, compared to the
comparable year earlier period. The Company may acquire additional oil and
gas interests, although it has no current plans to do so.
(7) STRATEGIC CONSIDERATIONS
In earlier stages of its development, the Company's strategic
emphasis focused on oil and gas production and development, particularly
of the substantial potential value possibly recoverable by waterflood of
the South Dog Creek field in Oklahoma and of the high quality but higher
fixed cost production in the San Juan Basin, New Mexico. The Company has
acquired and plans to continue to acquire interests in oil and gas
properties within its area of operation which are offered to it on
economically attractive terms. However, beginning in 1993 the Company
determined that a number of material adverse changes were occurring in the
independent oil and gas industry, including more extreme price volatility,
increasing costs of operation and a significantly more restricted market
for the acquisition of oil and gas properties or of other independent oil
and gas companies. These adverse developments have affected, in
particular, small oil and gas companies whose operations were not
diversified into other business sectors. In response to the changed
operating environment, the Company is actively considering transactions by
which its operations may be further diversified. In this process the
Company may reduce its oil and gas operations while adding significantly
to its participation in real estate, financial services or other sectors.
During late 1993 and 1994, the Company diversified outside of the
energy sector through acquisition of ownership interests in the commercial
real estate sector, in particular the office building in Houston, Texas
where the Company maintains its principal offices. The Company is actively
reviewing more substantial transactions outside the energy sector. While
such diversification appears to offer more attractive long-term
opportunities than are offered by the oil and gas sector currently, the
Company's ability to arrange financing to enter into a material
transaction is subject to a number of other factors, certain of which are
difficult to predict or are beyond management's control. Such factors
include the degree of the Company's future success in development of its
Page 14 of 24
<PAGE>
proved undeveloped reserves; the respective future performance of oil and
gas prices; and the availability to the Company of financing for existing
or other businesses.
End of Notes to Consolidated Financial Statements.
Page 15 of 24
<PAGE>
GOLDEN OIL COMPANY
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
LIQUIDITY AND CAPITAL RESOURCES
The Company's current operations emphasize oil and gas production and
development. Over the last several years, the Company has increased the size and
scope of its oil and gas operations through a number of corporate transactions,
primarily involving asset purchases and mergers. Corporate transactions also
have been undertaken or considered in other business sectors. To date, an
investment has been made in the real estate sector through acquisition of a
limited partnership interest in the Company' s headquarters office building in
Houston, Texas. The Company is seeking new operations and is actively reviewing
transactions involving diversification outside the energy sector.
The Company's operations during 1996, and to date during 1997, have been
funded primarily through internally generated funds from operating activities,
and from existing working capital and borrowings under its credit facilities.
Management anticipates that the Company will meet ordinary operating needs for
working capital from internal sources. However, the Company will require
additional financing in order to complete development of its proved undeveloped
reserves, or to make acquisitions either within or outside of the oil and gas
sector. The Company may arrange new financing through public or private
offerings of the Company's securities, asset sales, joint ventures, or other
means. If the Company is successful in its financing efforts, a significant use
of proceeds will be to improve its current working capital position.
In April 1996, the Company entered into a new credit agreement with a
commercial bank in Albuquerque, New Mexico ("Bank") under which the Company
increased the borrowings available to it from $150,000 to $400,000. In addition,
the maturity schedule of the Company's debt was extended to four years, subject
to certain conditions. Such credit facility was further required by the Bank to
be independently, personally guaranteed and to be collateralized by the
Company's New Mexico oil and gas properties.
Proceeds from the new credit facility have been utilized to refinance
short-term debt then outstanding; to acquire additional interests in oil and gas
properties offered to the Company by working interest holders on leases in which
the Company is operator; and to pay other payables. At March 31, 1996 the
Company had a working capital deficit of approximately $1,000,000. In order to
obtain the new financing the Company was required by the lending Bank to provide
a personal guarantee from a principal officer of the Company for repayment in
full to the Bank of all principal, interest and related costs. As a result of
its financial position, the Company was not able to pay a cash fee for the
personal guarantee required by the Bank as a condition of extending credit to
the Company. In lieu of cash payment, the Company proposed to pay the financing
fee by delivering to the guarantor warrants to purchase unregistered shares of
its common stock. On March 29, 1996 the Board of Directors approved execution by
the Company of the credit agreement of the Bank and the payment and delivery to
the guarantor of warrants to purchase 250,000 unregistered shares of common
stock of the Company through March 2006 for an
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<PAGE>
exercise price of $.20 per share. As of March 28, 1997, the guarantor had
exercised rights to purchase 100,000 shares of common stock granted under the
warrants. At June 30, 1997, the shares had not been issued by the Company and
delivered by the Company's transfer agent. Subsequent to June 30, 1997, such
shares were issued. Accordingly, such transaction will be reflected in the
financial statements in the third quarter of 1997.
Under the Company's new credit agreement, the Company is required to make
monthly payments of principal and interest, of approximately $10,400 through
April 2000. As of August 14, 1997, the Company had borrowed $341,000 and had
$59,000 remaining available under the new credit agreement.
The Company also maintained a credit facility in the original amount of
$100,000 with a commercial bank in Tulsa, Oklahoma and had borrowed $70,000
under such line of credit facility. In March 1996, the Company began reducing
the principal amount borrowed under this credit facility by $5,000 each month.
Such line of credit has been fully paid as of April 1997.
Cash flow provided by operating activities was $58,407 for the first six
months of 1997 compared to cash used by operating activities of $9,570 for the
first six months of 1996. The increase from the first six months of 1996 is
primarily due to increases in oil and gas prices and increased production
volumes derived from the purchase of additional interests in Company-operated
properties in New Mexico. Such increases were partially offset by net reductions
in working capital components, primarily trade payables.
In order to plan Company operations and to provide protection against
sudden declines in oil and gas prices, from time to time the Company enters into
fixed price oil sales contracts. During the first six months of 1997 the Company
maintained fixed price arrangements for approximately 60% of its monthly oil
production. These arrangements extend through July 1997 at an average wellhead
price of approximately $22 per barrel. During July 1997, the Company entered new
fixed price arrangements for 40% of its anticipated monthly oil volumes at a
price of approximately $18.50 per barrel through October 1997. The Company
believes it has entered into these fixed price arrangements with financially
capable purchasers and does not anticipate nonperformance by the counterparties
to such transactions. In the event of nonperformance by any of the
counterparties, the Company believes that, subject to future market prices, it
will be able to market its production to other parties under similar or then
market value terms and conditions.
In March 1993, an agreement was reached between the Company and Calumet
Oil Company, the principal operators in the South Dog Creek, Oklahoma field,
aimed at enhancing and extending the producing life of the field by injection of
water into the Mississippian formation in ten wells covering four separate
quarter section leases. The operators filed for a water injection permit with
the EPA, and during October 1993, a field-wide water injection permit was
granted by the EPA to the Company and another interest holder and operator.
During the fourth quarter of 1995 the Company initiated a limited waterflood
injection program on one of its operated leases believed to have demonstrated
engineering potential for success. The program involves converting certain
marginally producing wells to water injectors and reworking producing wells
Page 17 of 24
<PAGE>
and well equipment to increase the wells' fluid volume capacity. The cost of the
initial phase of the waterflood project on this lease through June 1997 was
approximately $222,000, exclusive of operating fees charged by the Company, of
which the Company's share was approximately $164,000. The Company funded its
share of costs through internal cash flows with the balance paid by outside
working interest owners who elected to join the project.
The Company is gradually increasing the rate and total volume of water
injected into the producing formation. Management will continue to evaluate the
results of current development before determining whether to undertake
additional development. The Company does not anticipate significant increases in
overall production volumes from the field unless further development is
implemented across a more extensive area and such further development is
successful. Currently, rates of injection have been increased to a total of
approximately 1,750 barrels of water per day into three (3) injection wells. To
date over 200,000 barrels of new water have been injected into the producing
formation; however, this volume is estimated to be at least 400,000 barrels
below the level at which localized repressurization may be expected to occur.
Based on indications available from the localized response to water injection to
date, the Company plans to continue its injection program. If sufficient
production response is achieved, the Company will pursue a field-wide
implementation of its waterflood plan. Determination as to full scale,
field-wide development for water injection remains subject to, among other
things, engineering advice based on the localized injection summarized above;
projected oil prices; and the availability of additional financing. At this
time, due to the variables discussed above, the Company is not able to provide a
definitive estimate of overall projected waterflood costs. As results are
received and analyzed, the Company will continue to review the historical costs
and the projected overall costs of the waterflood project. Subject to the
foregoing the Company is using a projection of $750,000, inclusive of costs
already incurred.
The Bureau of Land Management ("BLM") of the U.S. Department of the
Interior has implemented extensive national regulations for the handling and
maintenance of produced water from well sites on all federal lands. The stated
objective of the extensive new regulations is to provide guidance for closure of
unlined surface impoundments in a manner that assures protection of fresh
waters, public health and the environment. The regulations require oil and gas
companies to eliminate the use of unlined surface impoundments in the operation
of wells and to remediate and replace them with lined and enclosed surface pits.
Such new federal government regulations provide for implementation on a
region-by-region basis.
During January 1997, the designated regions were expanded to include
approximately 80 wells in the Company's field of operations in New Mexico.
Pursuant to the Company's operating permit from the Jicarilla Apache Indian
Nation, the Company's operating subsidiary has been required to develop a plan
for remediation and improvement for every well site. During May 1997 the BLM and
the Jicarilla Environmental Protection Office ("EPO") approved the initial phase
of the plan submitted ("Plan"). The Plan provided for the remediation and
enclosure of 14 surface pits located at the well sites by June 30, 1997 in
accordance with applicable Ordinance 95-0-308-03. Surface pits on such well
sites have been enclosed and soil remediation is continuing in accordance with
BLM and EPO regulations. Work is ongoing for an additional fifteen well sites.
Costs to date vary by well site but have ranged between $1,500 to $5,000 per
well site, or
Page 18 of 24
<PAGE>
approximately $55,000 in total, as to which the Company's pro-rata share
allocable to its working interest is approximately $28,000.
The required remediation on all well sites operated by the Company in New
Mexico is currently required to be completed by December 1998. Numerous oil and
gas producers in the region, including the Company, are seeking extensions to
such date but have not yet received such extension. The total cost of such work
is subject to a number of variable expense factors including, among others, the
cost and manner of disposal of removed soil and the amounts of soil that may be
required to be removed. The Plan allows relatively broad soil disposal options;
however, other more costly soil disposal alternatives may be deemed necessary or
may be mandated by the regulatory agencies governing the remediation and
impoundment programs.
Based upon the preliminary information available at this time, the Company
has estimated the total cost to complete the entire remediation and enclosure
program in the Company's operating area to be in the range of approximately
$200,000 to $500,000. Total costs could vary significantly from the Company's
estimate due to the numerous variable factors discussed above. In recognition of
the above factors the Company has charged a provision reflecting its preliminary
estimate of its share of such costs of $75,000 to earnings in the second quarter
of 1997. The adequacy of such provision will be reviewed by the Company as costs
are better established, and such provision may be increased in the future as
required.
At June 30, 1997, the Company had a working capital deficit of $887,641
compared to a working capital deficit of $988,596 at December 31, 1996, and a
current ratio of .35 to 1.00 as of June 30, 1997 compared to a current ratio of
.38 to 1.00 as of December 31, 1996. The decrease in the working capital deficit
at June 30, 1997 primarily reflects a decrease in trade payables and collections
of receivables from working interest participants.
On January 1, 1996 the Company adopted Statement of Financial Accounting
Standard ("SFAS") No. 121, "Accounting for the Impairment of Long-lived Assets
and for Long-lived Assets to be Disposed Of." There was no effect on the
financial position, results of operations or cash flows from the adoption of
this standard. In the future, however, pursuant to SFAS No. 121, material
negative adjustments to the carrying value of the Company's producing oil and
gas properties could be required should prices for oil and gas decline
significantly or if the Company were to revise its estimates of recoverable oil
and gas reserves.
In June 1997, the FASB issued Statement of Financial Accounting Standards
No. 130, "Reporting Comprehensive Income" ("Statement No. 130"). The statement
establishes standards for reporting and display of comprehensive income and its
components. In June 1997, the FASB also issued Statement of Financial Accounting
Standards No. 131, "Disclosures About Segments of an Enterprise and Related
Information" ("Statement No. 131"). The statement specifies revised guidelines
for determining an entity's operating and geographic segments and the type and
level of financial information about those segments to be disclosed. The Company
will adopt the provisions of Statements No. 130 and 131 in its 1998 financial
statements.
Due to factors including changes in tax laws, adverse changes in the
economics of exploration drilling and the availability to the Company of
alternative uses of capital, during the late 1980s the Company curtailed
exploration activities. If the Company commences such programs in the future, it
intends to continue its previous policy of sharing exploration risks with third
party drilling participants. Certain of the Company's oil and gas leases provide
for ongoing drilling arrangements for periodic development of proved reserves.
The Company's principal development obligations under such agreements have been
suspended pending clarification of title assignments on certain federal leases.
The Company expects to obtain drilling participation from industry partners so
as to reduce the amount of the Company's required drilling commitments.
Page 19 of 24
<PAGE>
GOLDEN OIL COMPANY
RESULTS OF OPERATIONS
COMPARISON OF THE THREE MONTHS ENDED JUNE 30, 1997 WITH THE THREE MONTHS ENDED
JUNE 30, 1996.
REVENUES
Revenues from oil and gas production increased from $316,912 during the
second quarter of 1996 to $456,344 in the comparable 1997 quarter, an increase
of $139,432. The increase is primarily attributable to an increase in average
oil price of $2.74 per barrel from $18.82 per barrel during the second quarter
of 1996 to $21.56 per barrel during the second quarter of 1997. Additionally,
average gas prices increased $0.47 per mcf from $0.92 per mcf during the second
quarter of 1996 to $1.39 per mcf during the second quarter of 1997. In addition,
production volumes increased 2,900 barrels and 9,300 mcf in the second quarter
of 1997 compared to the same period in 1996 primarily due to the Company
purchasing additional interests in Company-operated properties in New Mexico.
Other revenue was $6,886 for the second quarter of 1997 compared to $7,707
for the comparable period in 1996, primarily due to a decrease in gas gathering
and operating fees.
COSTS AND EXPENSES
Oil and gas production costs increased by $117,452 from $200,694 for the
second quarter of 1996 to $318,146 for the same period in 1997. Such increases
are primarily due to the production costs associated with the purchases of
additional interests in Company-operated properties in New Mexico and increased
operating costs related to the waterflood project in Oklahoma. Additionally, the
Company incurred additional costs of approximately $75,000 in the second quarter
of 1997 relating to the pit remediation plan in New Mexico. General and
administrative expenses increased by $17,077 from $82,299 for the second quarter
of 1996 to $99,376 for the same period in 1997. This increase is primarily due
to an increase in professional and consulting costs primarily related to the
implementation of a new electronic data processing system.
Depreciation, depletion and amortization expenses decreased from $99,810
for the second quarter of 1996 to $79,343 for the comparable period of 1997.
Loss on sale of property and equipment during the second quarter of 1997
of $7,552 reflects the sale of field equipment. Interest expense decreased by
$1,502 from $6,069 for the second quarter of 1996 to $4,567 for the same period
in 1997 due to a decrease in average outstanding borrowings.
Primarily reflecting the factors discussed above, the Company reported a
net loss for the three months ended June 30, 1997 of $46,974 compared to a net
loss of $69,151 for the same period of 1996.
Page 20 of 24
<PAGE>
GOLDEN OIL COMPANY
RESULTS OF OPERATIONS
COMPARISON OF THE SIX MONTHS ENDED JUNE 30, 1997 WITH THE SIX MONTHS ENDED JUNE
30, 1996.
REVENUES
Revenues from oil and gas production increased from $594,569 during the
first six months of 1996 to $878,708 in the comparable 1997 period, an increase
of $284,139. The increase is primarily attributable to an increase in average
oil price of $4.01 per barrel from $18.18 per barrel during the first six months
of 1996 to $22.19 per barrel during the first six months of 1997. Additionally,
average gas prices increased $0.91 per mcf from $0.99 per mcf during the first
six months of 1996 to $1.90 per mcf during the first six months of 1997. In
addition, average production volumes increased during the first six months of
1997 compared to the same period in 1996 as a result of the Company purchasing
additional interests in Company-operated properties in New Mexico.
Other revenue was $13,222 for the first six months of 1997 compared to
$14,713 for the comparable period in 1996, primarily due to a decrease in gas
gathering and operating fees.
COSTS AND EXPENSES
Oil and gas production costs increased by $231,557 from $393,165 for the
first six months of 1996 to $624,722 for the same period in 1997. Such increases
are primarily due to the production costs associated with the purchases of
additional interests in Company-operated properties, increased operating costs
related to the waterflood project in Oklahoma and performing an above-average
number of well workovers in its San Juan Basin field in New Mexico during the
first quarter of 1997. Additionally, the Company incurred additional costs of
approximately $75,000 in the second quarter of 1997 relating to the pit
remediation plan in New Mexico. General and administrative expenses increased by
$32,943 from $132,141 for the first six months of 1996 to $165,084 for the same
period in 1997. This increase is primarily due to an increase in professional
and consulting costs primarily related to the implementation of a new electronic
data processing system.
Depreciation, depletion and amortization expenses decreased from $201,966
for the first six months of 1996 to $160,906 for the comparable period of 1997.
Loss on sale of property and equipment during the first six months of 1997
of $7,552 reflects the sale of field equipment. Interest expense decreased by
$977 from $10,620 for the first six months of 1996 to $9,643 for the same period
in 1997 due to an increase in average outstanding borrowings.
Page 21 of 24
<PAGE>
As discussed more fully in Note 1 to the Consolidated Financial
Statements, the Company recognized a nonrecurring noncash charge during the
first six months of 1996 for the cumulative effect of a change in the accounting
method for depletion of $39,770.
Primarily reflecting the factors discussed above, the Company reported a
net loss for the first six months ended June 30, 1997 of $77,567 compared to a
net loss of $175,744 for the same period of 1996.
Page 22 of 24
<PAGE>
GOLDEN OIL COMPANY
PART II. OTHER INFORMATION
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K (MATERIAL EVENT).
(a) Exhibits
None.
(b) Reports on Form 8-K
None.
Page 23 of 24
<PAGE>
GOLDEN OIL COMPANY
SIGNATURES
Pursuant to the requirements of the Securities and Exchange Act of 1934, the
Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
GOLDEN OIL COMPANY
Date: August 14, 1997 By: /s/ RALPH T. McELVENNY, JR.
Chief Executive Officer
By: /s/ JEFFREY V. HOUSTON
Chief Financial and
Accounting Officer
Page 24 of 24
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<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> JUN-30-1997
<CASH> 138,440
<SECURITIES> 25,753
<RECEIVABLES> 290,520
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 484,076
<PP&E> 6,644,808
<DEPRECIATION> (3,705,777)
<TOTAL-ASSETS> 3,618,297
<CURRENT-LIABILITIES> 1,371,717
<BONDS> 0
0
0
<COMMON> 14,466
<OTHER-SE> 1,993,896
<TOTAL-LIABILITY-AND-EQUITY> 3,618,297
<SALES> 878,708
<TOTAL-REVENUES> 891,930
<CGS> 624,722
<TOTAL-COSTS> 950,712
<OTHER-EXPENSES> 9,142
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 9,643
<INCOME-PRETAX> (77,567)
<INCOME-TAX> 0
<INCOME-CONTINUING> (77,567)
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> (77,567)
<EPS-PRIMARY> (.05)
<EPS-DILUTED> (.05)
</TABLE>
