<PAGE> 1
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-KSB
(Mark One)
[X] Annual report pursuant to section 13 or 15(d) of the Securities
Exchange Act of 1934
For the fiscal year ended December 31, 1999 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 1-13513
UNITED STATES EXPLORATION, INC.
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(Name of small business issuer as specified in its charter)
Colorado 84-1120323
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(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1560 Broadway, Suite 1900, Denver, Colorado 80202
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(Address of principal executive offices) (Zip Code)
Issuer's telephone number: (303) 863-3550
Securities registered pursuant to Section 12(b) of the Act:
Title of each class Name of each exchange on which registered
Common Shares, $.0001 par value The American Stock Exchange
Check whether the issuer (1) filed all reports required to be filed by Section
13 or 15(d) of the Exchange Act during the past 12 months (or for such shorter
period that the registrant was required to file such reports), and (2) has been
subject to such filing requirements for the past 90 days. Yes X No
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Check if there is no disclosure of delinquent filers in response to Item 405 of
Regulation S-B in this form, and no disclosure will be contained, to the best of
the registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-KSB or any amendment to
this Form 10-KSB. [ ]
The Issuer's revenues for the most recent fiscal period were $8,177,716.
The aggregate market value of the common equity held by nonaffiliates of the
Company as of March 21, 2000, was approximately $13,309,424 based upon the last
reported sale of the Company's Common Shares on that date.
The total number of Common Shares outstanding as of March 21, 2000 was
15,620,631.
DOCUMENTS INCORPORATED BY REFERENCE:
None.
Transitional Small Business Disclosure Format: Yes No X
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TABLE OF CONTENTS
<TABLE>
<CAPTION>
PART I PAGE
<S> <C>
Items 1 and 2. Description of Business and Properties 1
Item 3. Legal Proceedings 8
Item 4. Submission of Matters to a Vote of
Security Holders 8
PART II
Item 5. Market for Common Equity and Related
Stockholder Matters 8
Item 6. Management's Discussion and Analysis or
Plan of Operation 10
Item 7. Financial Statements 17
Item 8. Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure 17
PART III
Item 9. Directors, Executive Officers, Promoters and
Control Persons; Compliance With Section
16(a) of the Exchange Act 18
Item 10. Executive Compensation 21
Item 11. Security Ownership of Certain Beneficial 24
Owners and Management
Item 12. Certain Relationships and Related Transactions 27
Item 13. Exhibits and Reports on Form 8-K 28
</TABLE>
Index to Financial Statements
Signature Page
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ADDITIONAL INFORMATION
Descriptions in this Report are qualified by reference to the contents
of any contract, agreement or other documents and are not necessarily complete.
Reference is made to each such contract, agreement or document filed as an
exhibit to this Report, or previously filed by the Company pursuant to
regulations of the Securities and Exchange Commission (the "Commission").
(See "Item 13. Exhibits and Reports on Form 8-K.")
FORWARD LOOKING STATEMENTS
See "Special Note Regarding Forward Looking Statements" at the end of
"Item 6. Management's Discussion and Analysis or Plan of Operation" for
cautionary statements concerning forward looking information contained in this
report.
<PAGE> 5
ITEMS 1. AND 2. DESCRIPTION OF BUSINESS AND PROPERTIES
GENERAL
United States Exploration, Inc. ("UXP" or the "Company") is an
independent producer of oil and natural gas. Our principal oil and gas
properties are located in the Wattenberg area of the Denver-Julesburg Basin in
northeastern Colorado. Those properties were acquired from Union Pacific
Resources Company ("UPR") in May of 1998. We also hold smaller interests in
Kansas and operate natural gas gathering systems located near certain of our
Kansas properties. In 1999, we sold our properties in Oklahoma in order to
concentrate our efforts on the Colorado properties.
OIL AND GAS PRODUCTION
Net oil and gas production (after royalties), average production costs
and average sales prices for the Company's products for the years ended December
31, 1999 and 1998 and for the nine-month transition period ended December 31,
1997 are shown in the table below:
NET OIL AND GAS PRODUCTION,
AVERAGE PRODUCTION COSTS AND SALES PRICES
<TABLE>
<CAPTION>
Net Production Average Sales Price
Production Cost Per --------------------------
---------------------------- Equivalent Per Bb1 Per Mcf
Period Oil (Mbbl) Gas(Mmcf) Unit(1) of Oil of Gas
- ------ ---------- --------- ------- ------ -------
<S> <C> <C> <C> <C> <C>
Year ended
December 31,
1999(2) 107.6 2,471 $ 5.38 $17.04 $2.14
Year ended
December 31,
1998(3) 140.1 1,650 6.76 13.07 1.71
Nine months
ended December
31, 1997 64.6 274 10.14 19.31 2.65
</TABLE>
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(1) Production cost per equivalent unit is calculated at the rate of 6 Mcf
of natural gas per Bbl of oil.
(2) Substantially all of the oil and gas production in 1999 is attributable
to the Colorado properties.
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(3) Approximately 54% of the oil production and 80% of the gas production
in 1998 was attributable to production from the Colorado properties
acquired from UPR during the period from the May 15, 1998 closing date
through year end. Approximately 31% of the oil production and 11% of
the gas production during 1998 was attributable to production from the
Oklahoma properties sold in January of 1999.
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Our natural gas is sold at prices determined on a monthly basis by
reference to various published spot prices for gas. For the last six months of
1999, approximately 20% of our Colorado gas was sold at a fixed price of
$1.92/Mmbtu (approximately $2.30/Mcf). Oil is also sold at prevailing spot
prices. During the year ended December 31, 1999, there were three purchasers or
operators who accounted for more than 10% of our revenues from purchased and
produced oil and gas sales. North American Resources Company, HS Resources and
Woodward Marketing purchased from the Company or sold for the Company's account
oil and gas constituting 51%, 15% and 11%, respectively, of total 1999 sales.
The loss of any of these purchasers would temporarily affect our revenues, but
we believe we will continue to have a market for our products for the
foreseeable future. (See Note 10 of Notes to Consolidated Financial Statements
for more detail.)
The availability of a ready market for our oil and gas depends upon
numerous factors beyond our control, including the extent of domestic production
and importation of oil and gas, the relative status of the domestic and
international economy, the proximity of our properties to gas gathering systems,
the capacity of such systems, the marketing of other competitive fuels, the
fluctuation in seasonal demands and governmental regulation of production,
refining, transportation and pricing of oil, natural gas and other fuels.
PROPERTIES
The following table summarizes our gross and net producing wells and
gross and net developed acres at December 31, 1999.
<TABLE>
<CAPTION>
Producing
Wells
-------------------------------------------------- Developed
Area Gas Oil Acres
- ---- ------------------- ------------------- ---------------------
Gross Net Gross Net Gross Net
----- --- ----- --- ----- ---
<S> <C> <C> <C> <C> <C> <C>
Colorado 307 152 68 43 44,773 42,330(1)
Kansas 12 12 -- -- 4,610 4,610
</TABLE>
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(1) The Company owns different interests in different productive or
potentially productive formations on many of its properties. The net acres
reflected in the table are based on the Company's interests in the formation
from which most of its production is derived (the J formation). The Company's
interest in shallower formations is somewhat smaller.
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We operate 81 of the Colorado wells in which we own an interest and all
of the Kansas wells in which we own an interest.
As part of our acquisition of the Colorado properties in May 1998, we
entered into an Exploration Agreement with UPR giving us the right to explore
and develop all of UPR's undeveloped acreage in the Wattenberg area of the
Denver-Julesburg Basin, excluding certain acreage already committed to other
agreements. The Exploration Agreement covers approximately 400,000 gross acres
and will also cover any undeveloped acreage currently committed to another
agreement that reverts to UPR during its term. The Exploration Agreement had an
initial term of 18 months and we have the right to renew the Exploration
Agreement for up to five 12-month option periods, assuming that we have drilled
the required number of commitment wells during the preceding period. We do not
have to extend the Exploration Agreement into a successive 12-month option
period unless we so elect. During the initial term, we drilled, deepened or
re-entered the required 15 commitment wells and elected to extend the
Exploration Agreement for the initial 12- month option period. We are required
to drill 20 commitment wells during the initial option period and each
succeeding 12-month option period to preserve our right to extend the
Exploration Agreement. If we do not drill the required number of commitment
wells during any option period for which the Exploration Agreement has been
extended, the Exploration Agreement will terminate at the end of the period and
we will be required to pay liquidated damages of $125,000 for each commitment
well that we did not drill during the period. If the Company is able to settle
its obligations to its principal lender on a satisfactory basis, management
believes that resources are available to satisfy the Company's commitment under
the Exploration Agreement during the initial option period. The failure to drill
the commitment wells during any option period would have a material adverse
effect on the financial condition and prospects of the Company. See "Item 6.
Management's Discussion and Analysis or Plan of Operation--Liquidity and Capital
Resources" and Note 15 of Notes to Consolidated Financial Statements.
In addition, the Exploration Agreement requires UPR to transfer to us
any working interests in wells in the subject area that UPR acquires under
existing agreements during the term of the Exploration Agreement. That
requirement covers a number of existing wells in which UPR has the right to
obtain a working interest or convert an overriding royalty interest into a
working interest after payout has been reached and will cover other wells that
may be drilled by operators with whom UPR has existing farm-out or similar
agreements. We also have the right to take over wells on the UPR lands that are
required to be offered to UPR prior to abandonment.
DRILLING ACTIVITY
The following table summarizes the Company's drilling activities during
the years ended December 31, 1999 and 1998 and the nine-month transition period
ended December 31, 1997:
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<TABLE>
<CAPTION>
Net New Net Re- Net
Wells(1)(2) Entries(1)(3) Deepenings(1)(4)
--------------------- --------------------- --------------------
Productive Dry Productive Dry Productive Dry
---------- --- ---------- --- ---------- ---
<S> <C> <C> <C> <C> <C> <C>
1999 1.38 .01 5.00 -- 6.49 .50
1998 -- -- -- -- 6.64 --
1997 -- -- -- -- -- --
</TABLE>
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(1) Net wells are the number of gross wells in which the Company
participated multiplied by the Company's interest in the well.
(2) Most of the new wells in 1999 were drilled under farm-out
arrangements pursuant to which the Company was carried on all costs through
commencement of production. There were five gross producing wells and two gross
dry holes included in the net well computations.
(3) Represents previously plugged well bores re-entered by the Company
to reestablish production. There were five gross producing wells included in the
net re-entries computations.
(4) Represents productive wells deepened to establish production from a
deeper formation. There were 16 gross producing wells and one gross dry hole
included in the net deepenings computations.
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All of the wells reflected in the table were development wells. The
Company is the operator of the five wells that were reentered in 1999. All of
the other wells reflected in the table are operated by other oil and gas
companies.
As of February 29, 2000, the Company was participating in the deepening
of five existing wells and the drilling of 12 new development wells under
farm-out arrangements pursuant to which all costs through the commencement of
production are paid by other parties. The farm-out arrangements provide that, if
actual costs exceed 105% of estimated costs computed on a quarterly basis for
wells commenced in that quarter, the Company is required to bear 22% of the
excess costs.
RESERVES
The following is a summary of the Company's estimated proved reserves
as of year-end 1999 and 1998:
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<TABLE>
<CAPTION>
December 31,
----------------------------------------------------------------------
1999 1998
-------------------------------- ----------------------------------
Kansas &
Kansas Colorado Total Oklahoma(1) Colorado Total
------- -------- -------- ----------- -------- --------
<S> <C> <C> <C> <C> <C> <C>
Crude Oil -
Mbbl -- 2,480.3 2,480.3 53.4 2,162.2 2,215.6
Natural Gas -
Mmcf 1,019.0 55,728.7 56,747.7 1,427.0 57,534.6 58,970.6
Total - Mmcfe 1,019.0 70,610.5 71,629.5 1,747.4 70,716.8 72,464.2
</TABLE>
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(1) Excludes reserves of 1,593 Mmcfe associated with Oklahoma
properties sold in January 1999.
Effective April 1, 1999 the Company sold its properties in Logan, Noble
and Kay Counties, Oklahoma containing reserves of approximately 540 Mmcfe. See
Note 18 of Notes to Consolidated Financial Statements for more detailed
information concerning changes in the Company's estimated oil and gas reserves
during 1999. For the year ended December 31, 1999, reserves were calculated
using prices of $24.10/Bbl of oil and $2.28 (Colorado) or $1.33 (Kansas) per Mcf
of natural gas. For the year ended December 31, 1998, reserves were calculated
using prices of $9.40/Bbl of oil and $1.84 (Colorado) or $1.74 (Kansas) per Mcf
of natural gas.
No reserve estimates were filed with any other federal authorities or
agencies since January 1, 1998.
FACILITIES
The Company occupies a portion of its executive and administrative
offices at 1560 Broadway, Suite 1900, Denver, Colorado, pursuant to a Cost and
Expense Sharing Agreement with Benson Mineral Group, Inc. ("BMG"), an affiliate
of Bruce D. Benson, Chairman of the Board, Chief Executive Officer and President
of the Company. Pursuant to that Agreement, the Company shares approximately
9,490 square feet of office space with BMG and pays its pro rata share of office
rent, personnel costs, administrative costs and expenses to BMG on a monthly
basis. After UXP obtained its own office lease in July, 1998, BMG stopped
charging any portion of its rent costs to UXP except for a portion of Bruce D.
Benson's office plus two file rooms, being a total of $2,968 monthly. The file
rooms were originally leased by BMG for use by the Company. During 1999, the
Company paid or accrued approximately $170,000 in rent and common expenses to
BMG under this agreement.
On July 1, 1998, UXP leased approximately 11,850 square feet of
additional office space adjacent to the space it shares with BMG. The additional
space was obtained to accommodate expansion in our operations following the UPR
acquisition. The term of the lease is 117 months. The
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rental is $14,817 per month, increasing to $19,410 per month after 57 months.
The Company is currently attempting to sub-lease substantially all of this
office space.
EMPLOYEES
At March 21, 2000, the Company had 15 employees, one of which is a
field employee and the remainder are executive and office personnel. Included in
this count is Bruce D. Benson, Chief Executive Officer and President of the
Company. The Company also engages independent contractors to supplement the
services of its employees as needed. At March 21, 2000, the Company was using
the services of approximately seven independent contractors on a full time
equivalent basis.
Pursuant to the Cost and Expense Sharing Agreement between the Company
and BMG, BMG and the Company share the services of ten employees of the Company
located in its executive and administrative offices. Such individuals include F.
Michael Murphy, Vice President and Secretary of the Company and Murray N.
Brooks, Vice President of Operations. Prior to February 22, 1999, the ten shared
employees were employed by BMG and the Company reimbursed BMG for a portion of
their salaries and benefits proportionate to the portion of their time spent on
UXP matters. Since February 22, 1999, these shared employees have been employed
by the Company and BMG reimburses the Company for the cost of time spent on BMG
matters. During 1998, the Company accrued or paid BMG approximately $558,000
under this arrangement. During 1999, the Company accrued or paid BMG
approximately $61,000 and BMG paid the Company approximately $346,000 under this
arrangement.
COMPETITION
The Company's competitors include major oil companies and other
independent operators, most of which have financial resources, staffs and
facilities substantially greater than those of the Company. Competition in the
oil and gas industry is intense. The Company also faces intense competition in
obtaining capital for drilling and acquisitions and is at a competitive
disadvantage compared with more established companies with proven records of
successful operations.
GOVERNMENT REGULATION
The production and sale of oil and gas are subject to various federal,
state and local governmental regulations, which may be changed from time to time
in response to economic or political conditions. Matters subject to regulation
include discharge permits for drilling operations, drilling bonds, reports
concerning operations, the spacing of wells, unitization and pooling of
properties, taxation and environmental protection. From time to time, regulatory
agencies have imposed price controls and limitations on production by
restricting the rate of flow of oil and gas wells below actual production
capacity in order to conserve supplies of oil and gas. Changes in these
regulations could have a material adverse effect on the Company.
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GLOSSARY OF TERMS
Bbls: Barrels of oil.
Bcfe: Billion cubic feet of gas equivalent, calculated on
the basis of six Mcf of gas for one Bbl of oil.
BTU: British Thermal Unit - the amount of heat necessary
to raise the temperature of one pound of water one
degree fahrenheit.
Gross acre: An acre in which a working interest is owned,
without regard to the size of the interest.
Gross well: An oil or gas well in which a working interest is
owned, without regard to the size of the interest.
Leases: Full or partial leasehold interests in oil and gas
prospects, authorizing the owner thereof to drill for,
reduce to possession and produce and sell oil and gas,
subject to the payment of rentals, bonuses and/or
royalties.
Mbbls: Thousand barrels.
MMBTU: Million BTU's.
Mcf: Thousand cubic feet.
Mmcf: Million cubic feet.
Mmcfe: Million cubic feet of gas equivalent, calculated on
the basis of six Mcf of gas for one Bbl of oil.
Net acres: One net acre is deemed to exist when the sum of
the fractional working interests owned in gross acres
equals one. The number of net acres is the sum of the
fractional working interests owned in gross acres.
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Net well: One net well is deemed to exist when the sum of
fractional working interests owned in gross wells
equals one. The number of net wells is the sum of the
fractional working interests owned in gross wells.
Proved Proved reserves that are expected to be recovered
Developed through existing wells with existing equipment and
Reserves: operating methods.
Proved Quantities of oil and gas which geological and
Reserves: engineering data demonstrate with reasonable
certainty to be recoverable in future years from
known reservoirs.
Proved Proved reserves that are expected to be
Undeveloped recovered from new wells or from existing wells
Reserves: where a relatively major expenditure is required
for recompletion.
ITEM 3. LEGAL PROCEEDINGS
The Company is not a party to any pending legal proceeding and the
property of the Company is not subject to any pending legal proceeding. The
Company is not aware of any proceeding that a governmental authority is
contemplating against the Company or its property. See "Item 6. Management's
Discussion and Analysis or Plan of Operations -- Liquidity and Capital
Resources" for a description of the status of the Company's principal credit
facility.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
There were no items submitted to a vote of the Company's Shareholders
during the quarter ended December 31, 1999.
ITEM 5. MARKET FOR COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
The Company's Common Stock is listed on the American Stock Exchange.
(See "Item 6. Management's Discussion and Analysis or Plan of Operations --
Liquidity and Capital Resources -- American Stock Exchange Listing" for
information concerning a pending review by the American Stock Exchange of the
Company's continued listing.) The following table sets forth the high and low
sales prices for the Common Stock on the American Stock Exchange for each
quarter of 1999 and 1998.
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<TABLE>
<CAPTION>
1999 HIGH LOW
- ---- ---- ---
<S> <C> <C>
Fourth Quarter $1.31 $0.69
Third Quarter $1.38 $0.69
Second Quarter $1.56 $0.94
First Quarter $2.13 $1.38
1998
- ----
Fourth Quarter $3.00 $1.25
Third Quarter $3.50 $1.88
Second Quarter $4.00 $2.50
First Quarter $3.31 $2.87
</TABLE>
The number of record holders of the Common Shares as of December 31,
1999 was 419. The Company estimates that there were approximately 1,500
beneficial owners of its Common Shares as of that date.
No dividends on the Common Shares have been paid by the Company to date
nor does the Company anticipate that dividends will be paid in the foreseeable
future. The terms of the Series C Preferred Stock of the Company currently
outstanding prevent the Company from paying any dividends on its common stock
until the Series C Preferred Stock is fully redeemed or converted. In addition,
the Company's principal credit facility prohibits the payment of dividends on
the Common Stock.
During 1999, the Company issued 100,000 shares of Common Stock upon
conversion of 50,000 shares of its Series C Preferred Stock in reliance upon the
exception afforded by Section 3(a)(9) of the Securities Act of 1933, as amended.
The conversion was effective as of June 30, 1998. For further discussion, see
"Item 6. Management's Discussion and Analysis or Plan of Action -- Results of
Operations - Year Ended December 31, 1999."
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ITEM 6. MANAGEMENT'S DISCUSSION AND ANALYSIS OR PLAN OF OPERATION
INTRODUCTION
In May 1998, we acquired our Colorado properties from UPR. Those new
properties are many times larger than the properties we have historically owned.
In January 1999 (effective December 31, 1998) we sold most of our Oklahoma
operations, and the remainder of our Oklahoma operations were sold effective
April 1, 1999. As a result of the Colorado acquisition in 1998 and the
dispositions of our Oklahoma operations in 1999, comparisons of 1999 and 1998
are not particularly meaningful.
As a result of the losses experienced by the Company in recent periods
and existing defaults under our principal loan agreement, our auditors have
included a "going concern" qualification in their opinion on our 1998 and 1999
financial statements. See "Index to Financial Statements - Reports of
Independent Auditors."
LIQUIDITY AND CAPITAL RESOURCES
Bank Credit Facility
On May 15, 1998, in connection with the UPR acquisition, we entered
into a Credit Agreement with ING (U.S.) Capital Corporation ("ING") establishing
a revolving credit facility (the "Credit Agreement"). Our obligations under the
Credit Agreement are secured by substantially all of our oil and gas properties.
We initially borrowed $29 million under the Credit Agreement to pay a portion of
the purchase price of the UPR properties. Since that time, additional borrowings
for working capital purposes, net of repayments from sale of properties, have
increased the principal balance of the loan to $31.25 million.
As of the end of the third quarter of 1998, we were not in compliance
with several of the financial covenants under the Credit Agreement. As a result,
the entire amount of the loan was classified as a current liability on our 1998
balance sheet. In September 1999, we stopped making required interest payments
on the loan. Effective October 1, 1999, interest began to accrue at the default
rate provided in the Credit Agreement (11.25% at December 31, 1999). At that
rate, interest accruals amount to approximately $300,000 per month. On March 28,
2000, ING accelerated the maturity of the loan and notified us of its intention
to proceed with foreclosure on the collateral. However, as of March 31, 2000,
the Company remained in active discussions with ING concerning the resolution of
the outstanding loan balances. Based on these discussions, the Company believes
that it could settle its obligations to ING for substantially less than the face
amount of the loan if it can obtain the funding necessary for such a settlement.
The Company is engaged in continuing negotiations with prospective lenders and
investors to provide the necessary financing for that purpose. However, the
Company cannot predict whether its efforts to raise such funds will be
successful soon enough to avoid foreclosure by ING. Foreclosure would result in
the sale of the
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Company's oil and gas properties and the application of the proceeds of the sale
to the payment of the ING debt. It is unlikely that the proceeds of that sale
would be sufficient to repay ING in full.
If the Company is able to raise the capital necessary to settle its
obligations to ING, it will require additional capital to develop its properties
in order to increase reserves and revenues and service any new debt incurred.
The Company is in discussions with a lender to obtain a line of credit for
development purposes. However, there can be no assurance that the Company will
be successful in obtaining that additional financing.
Capital Expenditures
As a result of the loan defaults described above, we significantly
curtailed projects requiring cash investment by the Company during 1999. We
intend to continue that policy until the situation with our lender has been
resolved.
In order to conserve capital, we entered into a farm-out arrangement in
November 1999 in which we granted an unaffiliated oil and gas company the right
to drill and complete up to 20 Colorado wells prior to December 31, 2000. The
other company will pay all of the costs to drill and complete the wells, and
will earn a 78% working interest in the wellbore of each well drilled and
completed as a producing well. At March 21, 2000, 16 wells have been or are in
the process of being drilled under this arrangement. Ten of these wells are
commitment wells under the Exploration Agreement described below which must be
commenced by November 30, 2000.
Under the Exploration Agreement described in Note 13 of the
Consolidated Financial Statements, we have an obligation to drill or commence
the drilling of 20 commitment wells during the 12-month period ending November
30, 2000. If the wells are not commenced by the deadline, the Exploration
Agreement is terminated and we will be obligated to pay liquidated damages of
$125,000 for each well not commenced. As of March 31, 2000, 10 commitment wells
have been or are in the process of being drilled. Management believes that the
remainder of the Company's commitment under the Exploration Agreement during the
current period will be satisfied.
In the UPR acquisition, we acquired a right of first refusal with
respect to a gas gathering system in the Wattenberg Field. During 1999, the
owner of that system proposed to sell it to another oil and gas company that
owns interests in (and operates) many of the wells in which we own interests. In
consideration of our waiver of the right of first refusal, we entered into an
agreement with the other operator that reduces our operating costs on many wells
and facilitates the development of our properties. That agreement became final
in December 1999 and so those cost reductions did not have a significant impact
on our results of operations for the year. Going forward, we expect the
operating cost reductions to total approximately $20,000/mo. The agreement also
included provisions for the settlement of a claim for gas imbalances (resulting
in a payment of $437,500 to the Company in 1999), the joint re-completion of
four wells (at an estimated cost to the Company of $140,000), the favorable
extension or modification of certain terms of existing gas gathering agreements,
operational changes in some joint agreements which make it easier to access
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our reserves without wellbore reimbursement costs and a farm-out to the Company
from the other operator of six recompletions and eleven deepenings. Finally, we
agreed with the other operator to use good faith efforts to negotiate an
agreement for the segregation of interests in J Sand and Dakota formation units
containing jointly owned wells (i.e., to exchange all of our interest in some
wells for all of the other operator's interest in other wells so that each of us
could simplify our operations).
Cash Balances and Cash Flow
As of March 21, 2000 the Company had cash and cash equivalents of
approximately $2.1 million. The increases in commodity prices and the
implementation of certain cost reduction measures are expected to produce
positive cash flow before capital spending in 2000. However, there can be no
assurance that prices will remain at current levels and that cash flow will be
positive.
Conversion of Series C Preferred Stock
In order to reduce the negative impact of preferred stock dividends on
earnings attributable to common shareholders and cash flow, we engaged in an
active program to convert Series C Preferred Stock into shares of common stock
during 1998. Since December 31, 1997, 3,391,834 shares of Series C Preferred
Stock have been converted into 6,783,668 shares of common stock. Most of these
conversions were effective immediately after the cash dividend was paid for the
second quarter of 1998. This conversion has reduced preferred stock dividend
requirements by approximately $1.6 million per year. The annual dividend
requirement on the 443,166 shares that remain outstanding is approximately
$213,000. However, no dividends have been paid on any of the Company's preferred
stock since June 30, 1998.
Property Sales
During the first quarter of 1999, we sold certain Oklahoma assets for
$1,825,000. On May 6, 1999, we sold our remaining Oklahoma assets for $750,000.
These sales did not result in any gain or loss to the Company as the proceeds
reduced the carrying cost of the Company's oil and gas property and equipment
full cost pool. The proceeds from these sales were applied to reduce the ING
loan.
American Stock Exchange Listing
The American Stock Exchange is conducting a review of the Company's
listing on the Exchange based upon its guidelines for continued listing and its
routine periodic review of the Company's SEC and other filings. The Company does
not meet the Exchange's guidelines for continued listing. The Company cannot
provide assurance that the Exchange will continue the listing of its Common
Stock. The de-listing of the Company's Common Stock could adversely affect its
ability to raise additional capital.
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RESULTS OF OPERATIONS
Introduction
Because of the acquisition of the UPR properties in May 1998,
comparison of the results of operations between the year ended December 31, 1999
and the year ended December 31, 1998 may not be very meaningful. Results of
operations for the year ended December 31, 1999 include Oklahoma operations in
Kay, Logan and Noble counties for four months and Colorado operations for the
entire year. Results of operation for the year ended December 31, 1998 include
Oklahoma operations for the entire year and Colorado operations for seven and
one-half months. The oil and gas properties involved in the UPR acquisition
dwarf the oil and gas properties previously owned by the Company. As a result,
sales of Company produced oil and gas and interest expense increased
substantially for the year ended December 31, 1999, while interest income
declined substantially. All interest expense is attributable to the UPR
acquisition and substantially all of the decrease in interest income results
from the use of Company cash in the 1998 UPR acquisition.
Year Ended December 31, 1999
The Company realized a net loss of $4,054,803 for the year compared to
a loss of $21,251,173 for the year ended December 31, 1998. Including preferred
stock dividends, the loss for the year was $4,267,523 or $0.27 per share.
Loss from operations was $1,457,241 for the year ended December 31,
1999 compared to $20,138,244 for the year ended December 31, 1998. Without
provisions for impairment of assets ($400,000 in 1999 related to the Texas land
held for resale; $15,351,987 in 1998, of which $145,000 related to the Texas
land held for resale and $15,206,978 related to the carrying value of the
Company's oil and gas property and equipment based upon engineering reserve
studies prepared as of December 31, 1998), the loss from operations is
$1,057,241 for 1999 and $4,786,266 for 1998. Substantially all of the decrease
in loss from operations from 1998 to 1999 can be attributed to increased
Colorado volumes sold at higher average sales prices, decreased production costs
per equivalent unit, and lower depletion, depreciation and amortization per unit
of production. As the table under "Items 1. and 2. Description of Business and
Properties - Oil and Gas Production" shows, gas sold in 1999 was 2,471,000 Mcf
at an average price of $2.14/Mcf compared to gas sold in 1998 of 1,650,000 Mcf
at an average price of $1.71/Mcf. Oil sold in 1999 was 107,600 Bbl at an average
price of $17.04/Bbl compared to oil sold in 1998 of 140,100 Bbl at an average
price of $13.07/Bbl. Production costs were $5.38 per equivalent Bbl in 1999
($0.90 per equivalent Mcf) as compared to $6.76 per equivalent Bbl ($1.13 per
equivalent Mcf) in 1998. The decrease in depletion, depreciation and
amortization for the Company's oil and gas property and equipment ($2,666,843 in
1999 compared to $3,669,802 in 1998) relates to a rate per equivalent Mcf or Bbl
established by reference to the engineering reserve studies prepared at December
31, 1999 and 1998. The 1998 engineering reserve study resulted in an impairment
of the carrying value of the Company's oil and gas property and equipment of
$15,206,978.
- 13 -
<PAGE> 18
Sales of purchased gas, net of gas acquisition costs and gathering and
transmission costs, provided a profit of $28,417 in 1999 compared to a loss of
$166,066 in 1998. These numbers are calculated before any amortization or
depreciation expense in either year. The improvement in results from 1998 to
1999 is attributable to the sale of certain marginal Oklahoma purchased gas
operations effective at the end of 1998 and the shut-in of the Kansas purchased
gas operations for five months during 1998.
General and administrative expenses increased from $2,157,044 for 1998
to $2,364,220 for 1999. The Colorado properties were acquired May 15, 1998 and
reflect only 7.5 months of increased costs related to this large acquisition,
although there were significant start up costs. Cost reduction measures were
implemented throughout 1999 and the Company is attempting to sub-lease
substantially all of its office space. The approximate minimum rental for this
office space for 1999 was $177,804.
Preferred stock dividends attributable to the year ended December 31,
1999 were $212,720, none of which were declared or paid. Preferred stock
dividends attributable to the year 1998 were $1,034,933 and include $118,360 for
the last two quarters of 1998 which were not declared or paid. Subsequent to
December 31, 1998, a preferred shareholder converted his preferred stock to
common stock effective June 30, 1998; therefore $12,000 of the $118,360
attributable to the last two quarters of 1998 is no longer due. The large
reduction in preferred stock dividends from 1998 to 1999 is attributable to the
conversion of preferred stock to common stock during 1998. Most of these
conversions were effective immediately after the cash dividend was paid for the
second quarter of 1998.
At December 31, 1999, dividends on the Series C Preferred Stock had not
been paid for 18 months. See "Item 9. Directors and Executive Officers" for a
discussion of additional directors to be added at the time preferred stock
dividends are in arrears for 18 months. If dividends are not paid on the Series
C Convertible Preferred Stock for three successive years, the Company may pay
all dividends in arrears in shares of its Common Stock, subject to the consent
of the holders of the Series C Preferred Stock. Such consent may not be withheld
for more than 180 consecutive days.
Year Ended December 31, 1998
The Company realized a net loss of $21,251,173 for the year compared to
a loss of $7,584,803 for the transition period (nine months) ended December 31,
1997. Including preferred stock dividends, the loss for the year was $22,286,106
or $1.67 per share.
The largest component of the net loss was a provision for impairment of
assets totaling $15,351,978, of which $15,206,978 was an adjustment to the
carrying value of the Company's oil and gas property and equipment based upon
engineering reserve studies prepared as of December 31, 1998. See "Items 1 and 2
Description of Business and Properties-Reserves" for a discussion of the
Company's oil and gas reserves. As a result of the reduction in estimated
reserves, the Company recorded an additional depletion, depreciation and
amortization expense in the fourth quarter of 1998
- 14 -
<PAGE> 19
totaling $2,558,311. Without the provision for impairment of the Company's oil
and gas property and equipment and the additional depletion, depreciation and
amortization expense recorded in the fourth quarter, the Company's net loss
would have been $3,485,884.
Because of the acquisition of the UPR properties in May 1998,
comparison of the results of operations between the year ended December 31, 1998
and the nine months ended December 31, 1997 is not meaningful. The oil and gas
properties involved in the UPR acquisition dwarf the oil and gas properties
owned by the Company at December 31, 1997. The Company initially borrowed
$29,000,000 in connection with the UPR acquisition and used some $11,000,000 of
existing cash to complete the acquisition. As a result, sales of Company
produced oil and gas, production costs of oil and gas, general and
administrative expenses and interest expense increased substantially, while
interest income declined substantially. Of the $4,376,561 in sales of Company
produced oil and gas, $3,144,919 are attributable to the UPR properties. Of the
$2,692,644 in production costs-oil and gas, $1,638,997 are attributable to the
UPR properties. All interest expense is attributable to the UPR acquisition and
substantially all of the decrease in interest income results from the use of
Company cash in the UPR acquisition. The increase in general and administrative
expense primarily results from additional personnel and associated costs, office
facilities and legal and accounting expenses, all of which are related to the
continuing operations of the UPR properties.
Sales of purchased gas and the related costs of gas acquisition and
gathering and transmission were somewhat affected by price, but the large
reduction in sales of purchased gas is attributable to the shut-in of the Kansas
gathering system for five months and the subsequent period of time needed to get
the gathering system completely functioning again after the shut-in period.
Preferred stock dividends attributable to the year ended December 31,
1998 are $1,034,933 and include $118,360 for dividends for the last two quarters
of 1998, which were not declared or paid and are not accrued on the balance
sheet. Preferred stock dividends attributable to the nine months ended December
31, 1997 were $1,421,226. Preferred stock dividends attributable to the three
months ended March 31, 1997 were $480,000. The comparison between the two
calendar years is $1,034,933 attributable to 1998 and $1,901,226 attributable to
1997. The large reduction is attributable to the conversion of preferred stock
to common stock during 1998. Most of these conversions were effective
immediately after the cash dividend paid for the second quarter of 1998.
Year 2000 Compliance
The Year 2000 issue did not produce any adverse effects to the
Company's systems before, on or after January 1, 2000. Additionally, the Company
did not experience any interruption in delivery of crucial supplies due to any
effects of the Year 2000 issue on third party suppliers.
- 15 -
<PAGE> 20
SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
Portions of this Report contain "forward-looking statements" within the
meaning of the federal securities laws. Such forward-looking statements include,
without limitation, statements regarding the Company's need for and potential
sources of capital, oil and gas reserves, future revenues and results of
operations, plans for future development operations and plans for dealing with
third parties, and are identified by words such as "anticipates," "plans,"
"expects," "intends" and "estimates." Factors that could cause actual results to
differ materially from these contemplated by such forward-looking statements
include, among others, the following:
Default on Credit Facility; Need for Additional Financing. The Company
is in default on its $31.25 million loan from ING, which is secured by
substantially all of its properties. ING has accelerated the loan and given
notice of its intention to foreclose. As described elsewhere in this report, the
Company is attempting to obtain the financing necessary to satisfy its
obligations to ING at a discount from the face amount of the loan. However,
there can be no assurance that such financing will be obtained soon enough to
avoid foreclosure by ING. In the event of a foreclosure, it is unlikely that the
proceeds of the sale of the Company's properties would be sufficient to pay off
the ING loan. In order to obtain the necessary financing, the Company would be
required to incur new debt or issue additional equity. The cost of debt to the
Company in its current situation would be high, and the price at which the
Company could sell equity would be low, with resulting significant dilution to
the Company's existing shareholders. In addition to the capital necessary to
resolve the ING loan, the Company will require additional capital to develop its
properties in order to increase reserves and revenues and service any new debt
incurred. There can be no assurance that such development capital will be
available on terms that are economic for the Company, or at all.
Reserve Estimates. The Company's estimates of proved reserves of oil
and gas and future net cash flows therefrom are based on various assumptions and
interpretations and, therefore, are inherently imprecise. Actual future
production, revenue, taxes, development expenditures, operating expenses and
quantities of recoverable oil and gas reserves may be subject to revision based
upon production history, results of future exploration and development,
prevailing oil and gas prices, operating costs and other factors. Revisions in
reserve estimates can affect the Company in various ways, including changes in
the borrowing base under its loan agreement, changes in depreciation, depletion
and amortization expense and, in the case of reductions in reserve estimates,
the need to create a provision for impairment of its oil and gas assets.
Reliance on Key Personnel. The Company is dependent upon its executive
officers and key employees, particularly Bruce D. Benson, its Chief Executive
Officer. The unexpected loss of the services of one or more of these individuals
could have a detrimental effect on the Company. The Company does not have key
person life insurance on any of its officers.
Effects of Growth. The acquisition of the UPR properties resulted in a
substantial change in the size and extent of the Company's assets and
operations. The Company expanded its facilities in anticipation of growth in its
operations staff that has not occurred to date as a result of the
- 16 -
<PAGE> 21
Company's lack of resources to pursue the development of its Colorado properties
at the anticipated rate and other factors. That expansion has resulted in
increased general and administrative expenses, principally the rent on
additional space leased by the Company. See Note 15 to the Financial Statements.
The Company is attempting to reduce its overhead by subleasing this additional
space, but there can be no assurance that it will be able to do so. In the
meantime, these increased general and administrative expenses will continue to
adversely affect the Company's results of operations and financial condition.
Availability of Services and Materials. The Company's expanded
operations will require significantly higher levels of third-party services and
materials. Such services and materials have at times been scarce and the
unavailability of a sufficient number of drilling rigs or other goods or
services could impede the Company's ability to achieve its objectives and
significantly increase the costs of its operations.
Oil and Gas Prices and Markets. The Company's revenues are dependent
upon prevailing prices for oil and gas. Oil and gas prices can be extremely
volatile. Prevailing prices are also affected by the actions of foreign
governments, international cartels and the United States government. Price
declines have in the past and may in the future adversely affect the Company,
both in lower prices received for its oil and gas and in reductions in the
estimated proved reserves attributable to the Company's properties. In addition,
the Company's revenues depend upon the marketability of production, which is
influenced by the availability and capacity of gas gathering systems and
pipelines, as well as the effects of federal and state regulation and general
economic conditions.
Government Regulation. Changes in government regulations applicable to
the production and sale of oil and gas may adversely affect the Company.
Most of these factors are beyond the control of the Company. Investors
are cautioned not to place undue reliance on forward-looking statements.
ITEM 7. FINANCIAL STATEMENTS
Reference is made to the Index to Financial Statements following the
Signature Page of this report for a listing of the financial statements included
in this report.
ITEM 8. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE
Previously reported.
- 17 -
<PAGE> 22
PART III
ITEM 9. DIRECTORS, EXECUTIVE OFFICERS, PROMOTERS AND CONTROL
PERSONS; COMPLIANCE WITH SECTION 16(a) OF THE EXCHANGE
ACT
DIRECTORS AND EXECUTIVE OFFICERS
The directors and executive officers of the Company are as follows:
<TABLE>
<CAPTION>
NAME AGE POSITION
- ---- --- --------
<S> <C> <C>
Bruce D. Benson 61 Chairman of the Board of
Directors, Chief Executive
Officer and President
Thomas W. Gamel 60 Director
Robert J. Malone 55 Director
Richard L. Robinson 70 Director
F. Michael Murphy 58 Chief Financial Officer, Vice
President and Secretary
Murray N. Brooks 57 Vice President of Operations
John Wallace 40 Vice President of Exploration
and Acquisitions
Kenton M. Scroggs 47 Vice President-Finance
Shirley Kovar 50 Vice President-Land
</TABLE>
Bruce D. Benson has been the Chairman of the Board of Directors, Chief
Executive Officer and President of the Company since August 1997. Since 1965,
Mr. Benson has been the owner and president of Benson Mineral Group, Inc.
("BMG"), a privately held company involved in oil and gas production, gas
processing and oil and gas pipeline operations. BMG and Mr. Benson have also
been active investors in a variety of other industries including real estate,
banking, mortgage servicing, cable television, management of real estate
investment trusts and franchise restaurants. Mr. Benson is a director of Asset
Investors Corporation, a publicly held company listed on the New York Stock
Exchange, and Commercial Assets, Inc., a publicly held company listed on the
American Stock Exchange. He is a trustee and past president and past chairman of
the Denver Area Council of the Boy Scouts of America, Chairman of the Denver
Zoological Foundation, National Chairman of the University of Colorado
Comprehensive Capital Campaign and past chairman of the Colorado Commission on
Higher Education.
Thomas W. Gamel has been a director of the Company since August 1997.
Since 1992, Mr. Gamel has served as chairman of Rockmont Value Investors, Ltd.,
a privately held investment company. He has been an owner and director of Timpte
Industries, Inc., a diversified private holding
- 18 -
<PAGE> 23
company, since 1970, and is an owner and director of several other private
companies. Mr. Gamel is a certified public accountant.
Robert J. Malone has been a director of the Company since August 1997.
From 1992 to 1996, Mr. Malone was the chairman and chief executive officer of
Colorado National Bank of Denver, Colorado (now US Bank of Denver, Colorado) and
has continued as the chairman of the board since 1996. From 1990 to 1992, he was
chairman of the board, president and chief executive officer of Western Capital
Investment Inc. and its principal subsidiary, Bank Western. Western Capital was
merged into First Bank Systems, Inc. (now U.S. Bancorp) in December 1992. He
presently serves on the Board of Commercial Assets, Inc., a publicly held
company listed on the American Stock Exchange. Mr. Malone has served on the
boards of several community and charitable organizations, including the Denver
Metro Chamber of Commerce, and is currently Chairman of the Board of Trustees of
Colorado's Ocean Journey and a Trustee of the Denver Zoological Foundation. He
is past-president of the Young Presidents Organization and past chairman of the
board of Regis University.
Richard L. Robinson has been a director of the Company since August
1997. Since 1975, Mr. Robinson has served as chairman or co-chairman of Robinson
Dairy, Inc. He also serves on the Board of Directors of several other companies,
including Asset Investors Corporation, a publicly held company listed on the New
York Stock Exchange, and Columbia/Health One. In addition to serving on the
Board of Directors of the Milk Industry Foundation, Mr. Robinson serves on the
Boards of many charitable and community organizations including Rose Community
Foundation, Regis University and Children's Hospital of Denver, Colorado.
F. Michael Murphy was appointed Chief Financial Officer, Vice President
and Secretary of the Company in August 1997. He has been employed by BMG since
1977, first as tax manager and since 1980 as chief financial officer. Mr. Murphy
is a certified public accountant, having begun his career with Arthur Young (now
Ernst & Young).
Murray N. Brooks has been the Vice President of Operations of the
Company since August 1997. Mr. Brooks has more than 30 years experience in the
oil and gas industry. He has been employed by BMG since 1984. During that time
he has worked in virtually every aspect of BMG's business with special emphasis
on management, engineering, production and drilling. From 1965 through 1984, Mr.
Brooks was employed by Husky Oil Company, rising to the division manager of the
Mid-Continent Region with overall responsibility for engineering.
John Wallace was appointed Vice President of Exploration and
Acquisitions in May 1998. For more than five years prior to joining the Company,
Mr. Wallace was President of The Esperanza Corporation, a privately held oil and
gas acquisition company, and Vice President of Dual Resources, Inc., a privately
held oil and gas exploration company. Esperanza has effected more than 25
acquisitions of producing properties throughout the United States. In addition,
Esperanza formed and administered royalty programs for private investors,
primarily in the Rocky Mountain region, and has participated in a number of
international exploration projects. Dual Resources is in the
- 19 -
<PAGE> 24
business of generating and selling exploration prospects, several of which have
resulted in new field discoveries.
Kenton M. Scroggs was appointed Vice President - Finance of the Company
on September 29, 1998. Mr. Scroggs currently provides services to the Company as
an independent consultant rather than as an employee and works for the Company
approximately two days a week. Prior to his appointment as an officer of the
Company, Mr. Scroggs was employed by Forest Oil Corporation where he served as
Vice President and Treasurer from 1993 through 1997.
Shirley Kovar was appointed Vice President-Land of the Company in
January 1999. Ms. Kovar joined UXP in April 1998 as Manager of the Land
Department. Prior to that she worked as an independent consultant in the oil and
gas industry for more than five years. Ms. Kovar has more than 27 years of
experience in the industry and is a member of the American, Colorado and Denver
Bar Associations.
Directors are elected annually to serve until the next annual meeting
of shareholders and until their successors are elected. Executive officers serve
at the pleasure of the Board. There is no family relationship between any of the
Company's directors or executive officers. Messrs. Benson, Murphy and Brooks
continue to serve as officers of BMG and do not devote their full business time
to the Company.
Under the terms of the Series C Convertible Preferred Stock, if
dividends have not been paid in an amount equal to at least six quarterly
dividends, the number of directors on the Company's Board is automatically
increased by two and the holders of the Series C Convertible Preferred Stock are
entitled to elect the two new directors. The Company is obligated to call a
meeting of the holders of the Series C Preferred Stock for the purpose of
electing those directors upon the written request of the holders of two-thirds
of the outstanding shares of Series C Preferred Stock. Upon payment of the
dividend arrearage, the size of the Board is reduced by two and the terms of the
directors elected by the holders of the Series C Preferred Stock automatically
terminate. On December 31, 1999, the dividend arrearages on the Series C
Convertible Preferred Stock totaled six quarters and this right of the holders
to elect two directors arose. At March 31, 2000, no written request from the
holders of the Series C Preferred had been received by the Company.
BOARD OF DIRECTORS' MEETINGS AND COMMITTEES
During 1999, the Company's Board of Directors met 12 times and took
action one time by unanimous written consent. Each of Messrs. Benson, Gamel,
Malone and Robinson were present, either in person or by telephone, at each
meeting of the Board of Directors and each committee of which he was a member
during the period he served as a director.
The Board of Directors of the Company maintains a standing Audit
Committee and a standing Compensation Committee. The Audit Committee is
responsible for reviewing and evaluating the Company's financial controls and
financial reporting obligations. The members of the
- 20 -
<PAGE> 25
Audit Committee are Messrs. Gamel (Chairman), Malone and Robinson. The
Compensation Committee is responsible for reviewing and evaluating the duties
and performance of the Company's officers and key employees and making
recommendations concerning their compensation. The members of the Compensation
Committee are Messrs. Malone (Chairman), Gamel and Robinson. During 1999, the
Audit Committee met once and the Compensation Committee met once. The Company
does not maintain a standing nominating committee.
COMPENSATION OF DIRECTORS
Each member of the Board of Directors who is not an employee of the
Company is entitled to receive $1,000 for each Board meeting and $500 for each
committee meeting not held in conjunction with a Board Meeting attended in
person or by telephone. Effective April 1, 1998, the Board of Directors adopted
a Director's Fee Stock Plan whereunder directors fees are paid in common stock
of the Company rather than in cash. The number of shares issued to each outside
director each year is determined by dividing the director's fees earned by that
director during the year by the average of the trading prices of the Company's
common stock on the first and last trading days of the year. If a director joins
or leaves the Board during the year, the day of his appointment or resignation
is substituted for the first or last trading day in that calculation. For their
services for 1999, the Company's outside directors were each issued 9,600 shares
of stock under the Plan and for their services from April 1 through December 31,
1998, the Company's outside directors were each issued 3,879 shares of stock
under this plan.
SECTION 16(a) BENEFICIAL OWNERSHIP REPORTING COMPLIANCE
Section 16(a) of the Securities Exchange Act of 1934 requires the
Company's directors and executive officers, and any persons who own more than 10
percent of the Company's Common Stock, to file with the Securities and Exchange
Commission initial reports of ownership and reports of changes in ownership of
Common Stock. The Company believes that all such Section 16(a) reports were
filed on a timely basis during the fiscal year ended December 31, 1999.
ITEM 10. EXECUTIVE COMPENSATION
The following table summarizes the total compensation for the Company's
Chief Executive Officer and its three other officers whose compensation exceeded
$100,000 for 1999 (the "Named Executive Officers"):
- 21 -
<PAGE> 26
<TABLE>
<CAPTION>
Summary Compensation Table
-------------------------------------------------
Annual Long-Term
Compensation Compensation
----------------------- ------------
Securities
Name and Salary Underlying All Other
Principal Position Year ($) Options(#) Compensation(1)
- ------------------ ---- --------- ----------- ---------------
<S> <C> <C> <C> <C>
Bruce D. Benson, 1999(2) $ 112,500 -- $ 4,046
Chairman of the 1998 150,000 -- 7,500
Board, Chief 1997(3) 53,077 4,000,000 --
Executive Officer
and President
John Wallace 1999 147,000 -- 7,511
Vice President of 1998 91,875 -- 4,594
Exploration and 1997 -- -- --
Acquisitions
F. Michael Murphy 1999 150,920(4) -- 7,546
Chief Financial 1998 --(4) 150,000 --(5)
Officer, Vice 1997 --(4) -- --(5)
President and
Secretary
Murray N. Brooks 1999 139,465(6) -- 6,973
Vice President of 1998 --(6) -- --(5)
Operations 1997 --(6) -- --(5)
</TABLE>
- ----------
(1) Consists of Company contributions to deferred contribution plan.
(2) Mr. Benson took no salary for July 1999 through September 1999. His
salary for October 1999 through December, 1999 ($37,500) is accrued but
not paid.
(3) From commencement of employment on August 7, 1997 through December 31,
1997.
(4) Mr. Murphy was on the BMG payroll until February 22, 1999 at which time
he was transferred to the Company payroll. The $150,920 shown above
reflects Mr. Murphy's salary for approximately 10 months. For the
period Mr. Murphy was on the BMG payroll, BMG billed the Company
$15,205 for Mr. Murphy's time spent on Company business. For the period
Mr. Murphy was on the Company payroll, the Company billed BMG $54,398
for time spent on BMG business. For 1998 and 1997, BMG billed the
Company $134,223 and $28,400, respectively, for time spent on Company
business.
- 22 -
<PAGE> 27
(5) During 1997 and 1998, Messrs. Murphy and Brooks were carried as
employees of BMG and contributions were made for their accounts by BMG
to the defined contribution plan in which BMG and the Company now
participate. The Company reimbursed BMG for a portion of such
contributions based on the percentage of time spent on Company affairs.
In 1997 and 1998, such reimbursements were $1,420 and $6,711,
respectively, for Mr. Murphy and $883 and $542, respectively for Mr.
Brooks.
(6) Mr. Brooks was on the BMG payroll until February 22, 1999 at which time
he was transferred to the Company payroll. The $139,465 reflects Mr.
Brooks' salary for approximately 10 months. For the period Mr. Brooks
was on the BMG payroll, BMG billed the Company $12,930 for Mr. Brooks'
time spent on Company business. For the period Mr. Brooks was on the
Company payroll, the Company billed BMG $107,896 for time spent on BMG
business. For 1998 and 1997, BMG billed the Company $108,411 and
$17,655, respectively, for time spent on Company business.
- ----------
No options were granted to or exercised by the Named Executive Officers
during 1999. The following table sets forth the value of unexercised options
held by the Named Executive Officers at December 31, 1999:
<TABLE>
<CAPTION>
1999 Year-End Option Values
---------------------------
Number of Securities
Underlying Unexercised Value of Unexercised
Options at Fiscal In-the-Money Options
Year End(#) at Fiscal Year end
Name Exercisable/Unexercisable ($)
- ---- ------------------------- ---------------------
<S> <C> <C>
Bruce D. Benson 4,000,000/0 (1)
F. Michael Murphy 50,000/100,000
</TABLE>
- ----------
(1) None of the unexercised options reflected in the table were
in-the-money as of December 31, 1999, based upon the last sales price
of the Common Stock on The American Stock Exchange on December 31, 1999
of $.6875.
- ----------
EMPLOYMENT AGREEMENT
The Company has an employment agreement with Mr. Benson dated August 7,
1997. The employment agreement provides for a base salary of not less than
$150,000 per year and bonuses at the discretion of the Board of Directors. It
has an initial term of three years, but renews automatically for successive
one-year terms unless terminated by either party. During the initial or any
renewal term, Mr. Benson's employment may be terminated at any time by the Board
of
- 23 -
<PAGE> 28
Directors, with or without cause, but Mr. Benson may terminate only upon the
occurrence of certain events, including a change in control of the Company as
defined in the employment agreement. The Company would not be required to pay
Mr. Benson any compensation as a result of or after any termination of his
employment. Mr. Benson is not required to devote his full business time to the
Company. Mr. Benson drew no salary for the period July, 1999 through September,
1999.
Pursuant to his employment agreement, Mr. Benson received options to
acquire up to 4,000,000 shares of the Company's Common Stock. These options were
to acquire 1,000,000 shares at $4.50 per share, 1,000,000 shares at $6.00 per
share, 1,000,000 shares at $9.00 per share and 1,000,000 shares at $12.00 per
share. All options were exercisable at December 31, 1999. All of the options
have a term of ten years from the date of the employment agreement. However, the
options would expire 90 days after the termination of Mr. Benson's employment
for cause, as defined in the employment agreement, or one year after Mr.
Benson's death or disability. The termination of employment for any other reason
would not affect the term of the options.
ITEM 11. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT
The following table sets forth as of December 31, 1999 the beneficial
ownership of each class of the Company's equity securities by Named Executive
Officers, each director of the Company and all directors and executive officers
as a group. The table also reflects the beneficial ownership of each class of
the Company's voting securities by each person known by the Company to own
beneficially more than 5% of any such class. As more fully described in "Item 9.
Directors, Executive Officers, Promoters and Control Persons; Compliance with
Section 16(a) of the Exchange Act -- Directors and Executive Officers," the
holders of the Series C Preferred Stock have the right to elect two directors if
dividends are in arrears for six quarters or more. That condition was fulfilled
as of December 31, 1999, and accordingly the Series C Preferred Stock is now
"voting stock" for purposes of applicable reporting requirements. Shares
issuable upon exercise of outstanding options that are currently exercisable or
will become exercisable within 60 days are treated as outstanding for the
purpose of computing the beneficial ownership of the person who holds the
options, but not for the purpose of computing the percentage ownership of any
other person or group. To the Company's knowledge, the shareholders listed below
have sole voting and investment power, except as otherwise noted. All
information is based upon filings with the Securities and Exchange Commission or
upon information provided to the Company.
- 24 -
<PAGE> 29
<TABLE>
<CAPTION>
Common Stock Series C Preferred Stock
------------------------------ ------------------------------
Name and Address of Number Percent of Number of Percent of
Beneficial Owner of Shares Class(1) Shares Series(1)
- ----------------------- --------- ----------- ------------- ----------
<S> <C> <C> <C> <C>
Bruce D. Benson 4,236,000(2) 21.59% -- --
1560 Broadway, Suite 1900
Denver, CO 80202
Thomas W. Gamel 402,267(3) 2.55% -- --
700 Broadway, Suite 800
Denver, CO 80202
Robert J. Malone 319,079(4) 2.02% -- --
335 St. Paul St.
Denver, CO 80202
F. Michael Murphy 50,000(7) 0.32% -- --
1560 Broadway, Suite 1900
Denver, Colorado 80202
Richard L. Robinson 323,579(4) 2.05% -- --
646 Bryant
Denver, CO 80202
Demetrie D. Carone 859,311(5) 5.50% -- --
6623 East 117th St.
Bixby, OK 74008
Dale M. Jensen 3,368,770 21.57% -- --
26796 N. 98th Way
Scottsdale, AZ 85255
Lancaster Ventures, LLC 916,668 5.87% -- --
5561 South 40th Street
Suite 220
Lincoln, NE 68516
Donald Dillon 916,668(6) 5.87% -- --
6600 South 56th Street
Lincoln, NE 68516
</TABLE>
- 25 -
<PAGE> 30
<TABLE>
<S> <C> <C> <C>
Thomas Stansfield 1,417,600 9.08% -- --
7052 East Fremont Place
Englewood, CO 80112
Charles D. Guyette 32,700 * 83,500 18.84%
4323 Ulysses Way
Golden, CO 80403
Keith R. Hesli 145,734 * 125,000 28.21%
1334 Sunny Lane
Anoka, MN 55303
Joseph A. Hutchinson 26,000 * 76,000 17.15%
27 Columbine Place
Castle Rock, CO 80104
Ram Development Company -- -- 25,000 5.64%
John Rinderknecht (Pres.)
10 Jackson Street
Denver, CO 80206
R.W. Rinderknecht Co. -- -- 75,000 16.92%
John Rinderknecht (Pres.)
P.O. Box 101298
Denver, CO 80250-1298
Charles D. Unruh 4,000 * 41,667 9.40%
12723 E. 111th St. North
Owasso, OK 74055
Directors and Executive
Officers as a Group 5,339,325(8) 26.41% -- --
(10 individuals)
</TABLE>
- ----------
(1) Based on 15,620,631 shares of Common Stock and 443,167 shares of
Series C Preferred Stock outstanding plus, in the case of each individual or
group, the number of shares that such individual has, or the members of such
group have, the right to acquire within 60 days after that date. The number of
shares of Common Stock outstanding, and the number of shares owned by Messrs.
Gamel, Malone and Robinson, have been increase by a total of 28,800 shares
issued pursuant to the Directors Fee Stock Plan after December 31, 1999 in
respect of services rendered during 1999.
- 26 -
<PAGE> 31
(2) Includes 4,000,000 shares of Common Stock underlying options that
are currently exercisable.
(3) Includes (i) 106,288 shares held indirectly through a corporation
of which Mr. Gamel has voting control and (ii) 179,000 shares of Common Stock
underlying options that are currently exercisable.
(4) Includes 179,000 shares of Common Stock underlying options that are
currently exercisable.
(5) Includes 419,261 shares held jointly with spouse.
(6) Includes 916,668 shares of Common Stock owned by Lancaster
Ventures, LLC, of which Mr. Dillon is a member.
(7) Includes 50,000 shares of Common Stock underlying options that are
currently exercisable.
(8) Includes an aggregate of 4,595,400 shares of Common Stock
underlying options that are currently exercisable.
* Less than 1%.
ITEM 12. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The Company shares certain facilities, equipment and personnel with BMG
pursuant to a Cost and Expense Sharing Agreement. Bruce D. Benson, Chairman of
the Board of Directors, Chief Executive Officer and President of the Company, is
also the President, a Director and sole shareholder of BMG. Pursuant to the Cost
and Expense Sharing Agreement, the Company reimburses BMG for office rent,
personnel costs and other overhead and administrative expenses associated with
operation of its business based upon actual use of the facilities and personnel
by the Company. The Cost and Expense Sharing Agreement is effective so long as
Mr. Benson's employment agreement is in effect. During the years ended December
31, 1999 and 1998, the Company paid or accrued an aggregate of $230,800 and
$660,570, respectively to BMG pursuant to this arrangement. Management believes
that the terms and conditions of this arrangement are no less favorable than
could be obtained from an unaffiliated third party or than could be obtained by
the Company in leasing separate office space and retaining separate personnel.
- 27 -
<PAGE> 32
ITEM 13. EXHIBITS AND REPORTS ON FORM 8-K
(a) EXHIBITS.
<TABLE>
<CAPTION>
EXHIBIT NO.
-----------
<S> <C>
3.1(1) Articles of Incorporation of the Company as filed on
January 9, 1989, with the Secretary of State of the
State of Colorado.
3.2(1) By-laws of the Company.
3.3(1) Articles of Amendment of the Company filed on June 7,
1990 with the Secretary of State of the State of
Colorado.
3.4(2) Articles of Amendment of the Company as filed with the
Secretary of State of the State of Colorado on September
24, 1996.
3.5(3) Amended and Restated Bylaws of the Company.
10.1(1) 1989 Incentive Stock Option Plan of the Company.
10.2(1) 1990 Non-Qualifying Stock Option Plan.
10.3.1(4) Lease Agreement between Mid-America Pipeline Company and
Producers Service, Incorporated.
10.3.2(4) Amendment to Lease Agreement between Mid-America
Pipeline Company and Producers Service, Incorporated.
10.4(5) Executive Employment Agreement, dated August 7, 1997, by
and between the Company and Bruce D. Benson.
10.5(5) Cost and Expense Sharing Agreement, dated August 7,
1997, by and between the Company and Benson Mineral
Group, Inc.
10.6(5) Form of Non-Qualified Stock Option Agreement.
10.7(6) Purchase and Sale Agreement between the Company and
Union Pacific Resources Company dated April 10, 1998.
10.8(6) Exploration Agreement between the Company and Union
Pacific Resources Company dated May 15, 1998.
</TABLE>
- 28 -
<PAGE> 33
<TABLE>
<S> <C>
10.9(6) Credit Agreement dated as of May 15, 1998 among the
Company and ING (U.S.) Capital Corporation.
10.10(6) Mortgage, Assignment, Security Agreement, Fixture Filing
and Financing Statement from United States Exploration,
Inc. to ING (U.S.) Capital Corporation, dated May 15,
1998.
10.11(6) Mortgage, Assignment, Security Agreement, Fixture Filing
and Financing Statement from Performance Petroleum Co.,
United States Gas Gathering Co., Inc. and Pacific Osage,
Inc. to ING (U.S.) Capital Corporation, dated May 15,
1998.
10.12(6) Pledge Agreement made as of May 15, 1998, by United
States Exploration, Inc., in favor of ING (U.S.) Capital
Corporation.
10.13(6) Guaranty made as of May 15, 1998, by Performance
Petroleum Co., United States Gas Gathering Co., Inc.,
Pacific Osage, Inc. and Producers Service Incorporated,
in favor of ING (U.S.) Capital Corporation.
10.14(7) Pipeline Purchase Agreement between USGG and Northern
Osage Gas Association L.L.C. dated as of December 31,
1998.
10.15(7) Stock Purchase Agreement between the Company and the
several buyers named therein relating to the sale of
USGG dated as of December 31, 1998.
10.16(7) Stock Purchase Agreement between the Company and
Demetrie D. Carone relating to the sale of Pacific and
Performance dated as of December 31, 1998.
10.17(8) Directors Fee Stock Plan.
10.18(8) Office Lease Agreement between the Company and EOP-One
Civic Center Plaza, L.L.C. dated October 15, 1998.
10.19(9) 1999 Employee Stock Option Plan.
10.20(10) Contract Amendment dated April 21, 1999 - Exploration
Agreement effective June 1, 1998 Wattenberg area Weld,
Arapahoe and Adams Counties, Colorado.
10.21(10) First Amendment to that certain Exploration Agreement
dated April 9, 1998 but effective as of June 1, 1998, by
and between Union Pacific Resources Company and United
States Exploration, Inc.
</TABLE>
- 29 -
<PAGE> 34
<TABLE>
<S> <C>
10.22 Agreement for Release and Termination dated November 20,
1999, by and among the Company, Kinder Morgan, Inc.,
formerly KN Energy, Inc., HS Resources, Inc. and
Resource Gathering Systems, Inc.
21(8) List of the Company's subsidiaries.
23.1 Consent of Ernst & Young LLP, independent certified
public accountants, to incorporation of this report by
reference into the Company's Registration Statement on
Form S-8 (Registration No. 333-60983).
24 Powers of Attorney.
27 Financial Data Schedule.
</TABLE>
- ----------
(1) Filed as an Exhibit to Form S-18 dated March 8, 1989 and
incorporated herein reference.
(2) Filed as an Exhibit to Form 8-K dated September 30, 1996 and
incorporated herein by reference.
(3) Filed as an Exhibit to Form S-8 filed August 7, 1998 (Registration
No. 333-60983) and incorporated herein by reference.
(4) Filed as an Exhibit to Form 10-KSB for the fiscal year ended March
31, 1994 and incorporated herein by reference.
(5) Filed as an Exhibit to Form 10-QSB for the quarter ended June 30,
1997, and incorporated herein by reference.
(6) Filed as an Exhibit to Form 8-K dated May 26, 1998 and incorporated
herein by reference.
(7) Filed as an Exhibit to Form 8-K dated February 2, 1999 and
incorporated herein by reference.
(8) Filed as an Exhibit to Form 10-KSB for the year ended December 31,
1998 and incorporated herein by reference.
(9) Filed as Exhibit A to the Proxy Statement of United States
Exploration, Inc. Annual Meeting of Shareholders held July 13, 1999 and
incorporated herein by reference.
- 30 -
<PAGE> 35
(10) Filed as an Exhibit to Form 10-QSB for the quarter ended March 31,
1999 and incorporated herein by reference.
(b) REPORTS ON FORM 8-K.
No reports on Form 8-K were filed during the fourth quarter of 1999.
- 31 -
<PAGE> 36
SIGNATURE
In accordance with Section 13 or 15(d) of the Exchange Act, the
registrant has caused this report to be signed on its behalf by the undersigned,
thereunto duly authorized.
UNITED STATES EXPLORATION, INC.
By: /s/ F. Michael Murphy
---------------------------------------
F. Michael Murphy, Vice President
Date: April 13, 2000
-------------------------------------
In accordance with the Exchange Act, this report has been signed by the
following persons on behalf of the registrant and in the capacities and on the
dates indicated.
<TABLE>
<CAPTION>
Signatures Title Date
- ---------- ----- ----
<S> <C> <C>
/s/ F. Michael Murphy Vice President, Chief Financial April 13, 2000
- -------------------------
F. Michael Murphy Officer and Secretary (Chief
Financial and Accounting
Officer)
Bruce D. Benson President, Chief Executive
Officer, and Chairman of
the Board of Directors
Thomas W. Gamel Director
Robert J. Malone Director
Richard L. Robinson Director
By: /s/ F. Michael Murphy April 13, 2000
-------------------------
F. Michael Murphy
Attorney-In-Fact
</TABLE>
- 32 -
<PAGE> 37
United States Exploration, Inc. and Subsidiaries
Consolidated Financial Statements
Years ended December 31, 1999 and December 31, 1998
CONTENTS
<TABLE>
<S> <C>
Report of Independent Auditors ........................................................................F-1
Audited Consolidated Financial Statements
Consolidated Balance Sheets............................................................................F-2
Consolidated Statements of Operations..................................................................F-4
Consolidated Statements of Changes in Stockholders' Equity.............................................F-5
Consolidated Statements of Cash Flows .................................................................F-6
Notes to Consolidated Financial Statements ............................................................F-7
</TABLE>
<PAGE> 38
Report of Independent Auditors
Board of Directors
United States Exploration, Inc.
We have audited the accompanying consolidated balance sheets of United States
Exploration, Inc. and subsidiaries as of December 31, 1999 and 1998, and the
related consolidated statements of operations, changes in stockholders' equity
and cash flows for the years then ended. These financial statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally accepted
in the United States. Those standards require that we plan and perform the audit
to obtain reasonable assurance about whether the financial statements are free
of material misstatement. An audit includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial statements. An audit
also includes assessing the accounting principles used and significant estimates
made by management, as well as evaluating the overall financial statement
presentation. We believe that our audits provide a reasonable basis for our
opinion.
In our opinion, the financial statements referred to above present fairly, in
all material respects, the consolidated financial position of United States
Exploration, Inc. and subsidiaries at December 31, 1999 and 1998, and the
consolidated results of their operations and their cash flows for the years then
ended in conformity with accounting principles generally accepted in the United
States.
The accompanying financial statements have been prepared assuming that United
States Exploration, Inc. and subsidiaries will continue as a going concern. As
more fully described in Note 2, the Company has incurred operating losses and is
currently in default of certain covenants and required interest payments with
respect to its note payable with a bank. The Company has received official
notice of acceleration from the bank and of the bank's intent to proceed with
foreclosure. These conditions raise substantial doubt about the Company's
ability to continue as a going concern. Management's plans in regard to this
matter are also described in Note 2. The financial statements do not include any
adjustments to reflect the possible future effects on the recoverability and
classification of assets or the amounts and classification of liabilities that
may result from the outcome of this uncertainty.
Denver, Colorado /s/ Ernst & Young LLP
March 20, 2000, except for Notes 2 and 17,
as to which the date is March 28, 2000
F-1
<PAGE> 39
United States Exploration, Inc. and Subsidiaries
Consolidated Balance Sheets
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
----------- -----------
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents $ 3,096,691 $ 1,000,661
Accounts receivable 1,308,015 2,980,700
Due from related parties 41,764 4,761
Inventory 2,792 9,684
Prepaid expenses and deposits 64,717 806,947
Assets held for sale -- 1,825,000
----------- -----------
Total current assets 4,513,979 6,627,753
Property and equipment, at cost, net:
Oil and gas property and equipment 24,720,045 25,166,770
Natural gas gathering systems 949,229 977,050
Other equipment and leasehold improvements 313,661 295,046
----------- -----------
25,982,935 26,438,866
Other assets:
Land held for resale 300,000 700,000
Pipeline lease, less accumulated amortization
of $298,915 and $244,950 at
December 31, 1999 and 1998, respectively 408,393 462,358
Loan costs, less accumulated amortization
of $116,208 and $44,695 at December 31, 1999
and 1998, respectively 357,563 429,076
----------- -----------
1,065,956 1,591,434
----------- -----------
Total assets $31,562,870 $34,658,053
=========== ===========
</TABLE>
F-2
<PAGE> 40
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
LIABILITIES AND STOCKHOLDERS' DEFICIT
Current liabilities:
Accounts payable $ 2,885,830 $ 2,365,983
Accrued liabilities 260,265 171,209
Due to related parties 14,878 47,379
Due bank under credit facility 31,250,000 31,900,000
Accrued interest--credit facility 1,288,458 279,240
------------ ------------
Total current liabilities 35,699,431 34,763,811
Commitments and contingencies
Stockholders' equity:
Preferred stock - $.01 par value
Authorized Series C Cumulative Convertible -
100,000,000 shares
Issued and outstanding - 443,166 and 493,166
shares at December 31, 1999 and 1998,
respectively (liquidation preference of $2,978,076
and $3,077,356 at December 31, 1999 and 1998,
respectively) 2,658,996 2,958,996
Common stock - $.0001 par value:
Authorized - 500,000,000 shares
Issued and outstanding -15,591,831 and
15,480,194 shares at December 31, 1999 and
1998, respectively 1,559 1,548
Capital in excess of par value 32,901,042 32,577,053
Accumulated deficit (39,698,158) (35,643,355)
------------ ------------
Total stockholders' deficit (4,136,561) (105,758)
------------ ------------
Total liabilities and stockholders' deficit $ 31,562,870 $ 34,658,053
============ ============
</TABLE>
See accompanying notes.
F-3
<PAGE> 41
United States Exploration, Inc. and Subsidiaries
Consolidated Statements of Operations
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
REVENUES
Sale of purchased gas $ 946,785 $ 844,437
Sale of company produced oil and gas 7,144,849 4,376,561
Contracting and operating fees 86,082 58,923
------------ ------------
8,177,716 5,279,921
COSTS AND EXPENSES
Gas acquisition costs 518,337 406,228
Gathering and transmission costs 400,031 604,215
Production costs--oil and gas 2,792,146 2,692,644
Other operating expenses 114,787 118,316
Depletion, depreciation and amortization 3,045,436 4,087,740
Provision for impairment of assets 400,000 15,351,978
General and administrative expenses 2,364,220 2,157,044
------------ ------------
9,634,957 25,418,165
Loss from operations (1,457,241) (20,138,244)
OTHER INCOME (EXPENSE)
Interest income 68,348 332,674
Interest expense (2,666,314) (1,431,563)
Other 404 (14,040)
------------ ------------
Net loss (4,054,803) (21,251,173)
Preferred stock dividends applicable to the period (212,720) (1,034,933)
------------ ------------
Net loss applicable to common stockholders $ (4,267,523) $(22,286,106)
============ ============
Basic and diluted loss per common share $ (0.27) $ (1.67)
============ ============
Weighted average common shares outstanding 15,591,831 13,322,519
============ ============
</TABLE>
See accompanying notes.
F-4
<PAGE> 42
United States Exploration, Inc. and Subsidiaries
Consolidated Statements of Changes in Stockholders' Equity
Year ended December 31, 1999 and 1998
<TABLE>
<CAPTION>
SERIES C COMMON STOCK CAPITAL IN
---------------------------- --------------------------- EXCESS OF
SHARES AMOUNT SHARES AMOUNT PAR VALUE
---------- ------------ ---------- ------------ ------------
<S> <C> <C> <C> <C> <C>
Balance, December 31, 1997 3,835,000 $ 23,010,000 8,795,400 $ 880 $ 12,523,345
Conversion of preferred stock to
common stock (3,341,834) (20,051,004) 6,683,668 668 20,050,336
Dividends on Series C
preferred stock -- -- 1,126 -- 3,372
Net loss for the year -- -- -- -- --
---------- ------------ ---------- ------------ ------------
Balance, December 31, 1998 493,166 2,958,996 15,480,194 1,548 32,577,053
Conversion of preferred stock to
common stock (50,000) (300,000) 100,000 10 299,990
Issuance of common stock for
director's compensation -- -- 11,637 1 23,999
Net loss for the year -- -- -- -- --
---------- ------------ ---------- ------------ ------------
Balance, December 31, 1999 443,166 $ 2,658,996 15,591,831 $ 1,559 $ 32,901,042
========== ============ ========== ============ ============
<CAPTION>
ACCUMULATED
DEFICIT TOTAL
------------ ------------
<S> <C> <C>
Balance, December 31, 1997 $(13,475,611) $ 22,058,614
Conversion of preferred stock to
common stock -- --
Dividends on Series C
preferred stock (916,571) (913,199)
Net loss for the year (21,251,173) (21,251,173)
------------ ------------
Balance, December 31, 1998 (35,643,355) (105,758)
Conversion of preferred stock to
common stock -- --
Issuance of common stock for
director's compensation -- 24,000
Net loss for the year (4,054,803) (4,054,803)
------------ ------------
Balance, December 31, 1999 $(39,698,158) $ (4,136,561)
============ ============
</TABLE>
See accompanying notes.
F-5
<PAGE> 43
United States Exploration, Inc. and Subsidiaries
Consolidated Statements of Cash Flows
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
CASH FLOWS FROM OPERATIONS
Net loss $ (4,054,803) $(21,251,173)
Adjustments to reconcile net loss to net cash
provided by (used in) operating activities:
Depreciation, depletion and amortization 3,045,436 4,087,740
Provision for impairment of assets 400,000 15,351,978
Loss on sale of assets 6,813 20,827
Stock issued as compensation 24,000 --
Provision for doubtful accounts 15,061 --
Decrease (increase) in accounts receivable, net 1,657,624 (2,418,684)
Increase in due from related parties (37,003) (4,761)
Decrease in inventory 6,893 5,205
Decrease (increase) in prepaid expenses 742,230 (775,680)
Increase in accounts payable and accrued expenses 1,618,121 2,411,268
Decrease in due to related parties (32,501) (14,955)
Other -- 1,999
------------ ------------
Net cash provided by (used in) operating activities 3,391,871 (2,586,236)
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (3,253,641) (2,954,355)
Proceeds from sale of assets 1,825,000 --
Proceeds from sale of equipment 782,800 62,865
Acquisition of oil and gas leases -- (39,559,220)
------------ ------------
Net cash used in investing activities (645,841) (42,450,710)
CASH FLOWS FROM FINANCING ACTIVITIES
Repayment of note payable to bank (3,350,000) --
Proceeds from note payable to bank 2,700,000 31,900,000
Loan costs related to acquisition financing -- (473,772)
Dividend paid on preferred stock -- (1,376,773)
------------ ------------
Net cash (used in) provided by financing activities (650,000) 30,049,455
Net increase (decrease) in cash and cash equivalents 2,096,030 (14,987,491)
Cash and cash equivalents, beginning of year 1,000,661 15,988,152
------------ ------------
Cash and cash equivalents, end of year $ 3,096,691 $ 1,000,661
============ ============
Noncash investing and financing activities:
Conversion of preferred stock and accrued dividends to
shares of common stock $ 300,000 $ 20,051,004
Preferred dividends paid with common stock -- 3,372
Liabilities assumed with acquisition -- 355,881
Cash paid during the year for interest 1,657,096 1,152,144
</TABLE>
See accompanying notes
F-6
<PAGE> 44
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements
December 31, 1999 and 1998
1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
COMPANY HISTORY AND NATURE OF OPERATIONS
United States Exploration, Inc. (the Company) was incorporated on January 9,
1989. The Company operates as a producer of oil and gas, and as an operator of
gas gathering systems. The Company's operations are currently located in
southeast Kansas and, effective May 1998, northeast Colorado. During 1999, the
Company sold all of its operations located in northeast Oklahoma.
PRINCIPLES OF CONSOLIDATION
The accompanying consolidated financial statements include the accounts of
United States Exploration, Inc. and its wholly owned subsidiaries, Producers
Service Incorporated, Performance Petroleum Corporation, Pacific Osage, Inc.,
and United States Gas Gathering Co., Inc. (formerly ZCA Gas Gathering, Inc.). On
January 20, 1999, the stock of Performance Petroleum Corporation, Pacific Osage,
Inc. and United States Gas Gathering Co. Inc. was sold in two separate
transactions. All significant intercompany transactions and balances have been
eliminated in consolidation.
USE OF ESTIMATES
The preparation of financial statements in conformity with generally accepted
accounting principles requires management to make estimates and assumptions that
affect the amounts reported in the financial statements and accompanying notes.
Actual results could differ from those estimates.
REVENUE RECOGNITION
The Company accounts for gas imbalances using the sales method. Under this
method, revenue is recognized based on cash received rather than the Company's
proportionate share of gas produced. During 1999, the Company received $437,500
as settlement of a gas imbalance existing at December 31, 1998. The Company does
not have a significant imbalance situation at December 31, 1999.
Revenues from the purchase, sale and transportation of purchased natural gas are
recognized when transported volumes are delivered.
The Company recognizes oil sales on delivery.
F-7
<PAGE> 45
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
CASH EQUIVALENTS
For purposes of the statements of cash flows, the Company considers all highly
liquid debt instruments purchased with a maturity of three months or less to be
cash equivalents. Cash equivalents at December 31, 1999 are comprised of
$944,340 of Neptune Funding Commercial Paper which matured January 24, 2000. The
Company had no cash equivalents at December 31, 1998.
OIL AND GAS INTERESTS
The Company follows the full cost method of accounting as defined by the
Securities and Exchange Commission, whereby all costs incurred in connection
with the acquisition, exploration and development of oil and gas properties,
whether productive or unproductive, are capitalized. Capitalized costs which
relate to proved properties and estimated future costs to be incurred in the
development of proved reserves and estimated future dismantlement and
abandonment costs are amortized using the units-of-production method.
Capitalized costs associated with significant investments in unproved properties
are excluded from the amortization base until such time as these properties are
evaluated. Additionally, no gains or losses are recognized upon the disposition
of oil and gas properties. Capitalized costs are subjected to periodic tests of
recoverability by comparison to the present value of future net revenues from
proved reserves. Any capitalized costs in excess of the present value of future
net revenues from proved reserves, adjusted for the cost of certain unproved
properties, are charged to expense in the year such excess occurs.
PROPERTY AND EQUIPMENT
Property and equipment, exclusive of property and equipment included in the full
cost pool, is stated at cost and depreciated using the straight-line method over
the estimated useful lives of the assets as follows:
<TABLE>
<S> <C>
Leasehold improvements 10 years
Natural gas gathering systems 10-17 years
Equipment 5-7 years
</TABLE>
Maintenance, repairs and renewals which neither materially add to the value of
the asset nor appreciably prolong its life are charged to expense as incurred.
Gains or losses on dispositions of these assets are included in operations.
F-8
<PAGE> 46
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
The capitalized pipeline lease agreement is being amortized using the
straight-line method over the remaining term of the lease.
The capitalized loan costs are being amortized over the stated term of the
credit facility.
INCOME TAXES
United States Exploration, Inc. and its subsidiaries file a consolidated federal
income tax return. Deferred income taxes are based on the liability method as
prescribed by Statement of Financial Standards No. 109, Accounting for Income
Taxes (SFAS 109). Under SFAS 109, deferred income taxes are provided for
temporary differences in recognizing certain income and expense items for
financial reporting and tax reporting purposes.
STOCK OPTIONS
The Company has elected to follow Accounting Principles Board Opinion No. 25,
Accounting for Stock Issued to Employees (APB 25), and related interpretations
in accounting for outstanding stock options. Under APB 25, when the exercise
price of the Company's stock options equals or exceeds the market price of the
underlying stock on the date of grant, no compensation expense is recognized. If
the market price of the underlying stock on the date of grant exceeds the
exercise price of the Company's stock options, compensation expense would be
recognized.
LOSS PER SHARE
Basic loss per share is computed by dividing net loss applicable to common
stockholders by the weighted-average common shares outstanding for the period.
Diluted loss per share reflects the potential dilution that could occur if
common stock options were exercised and preferred stock was converted into
common stock. Basic and diluted loss per share are the same for all periods
presented as the exercise of stock options and the conversion of preferred stock
have an antidilutive effect on all periods.
RECLASSIFICATIONS
Certain reclassifications have been made to the 1998 financial statements to
compare with the 1999 financial statement presentation.
F-9
<PAGE> 47
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
2. FINANCIAL RESULTS AND LIQUIDITY
The Company has incurred net losses of $4,054,803 and $21,251,173 for the years
ended December 31, 1999 and 1998, respectively. Included in these amounts are
provisions for impairment of assets of $400,000 and $15,351,978, respectively.
The Company is not in compliance with certain covenants under a credit facility
with a bank. In addition, the Company has not made scheduled interest payments
due since September 1999. As a result, the loan is in default. On March 28,
2000, the bank gave the Company official notice of acceleration and of its
intention to proceed with foreclosure. Accordingly, $31,250,000 of principal
outstanding at December 31, 1999 under the credit facility has been classified
as a current liability in the accompanying balance sheet. As more fully
described in Note 17, the Company's management is evaluating its options and
continuing its discussions with the bank.
3. RELATED PARTY TRANSACTIONS
In 1997, the Company relocated its principal executive office from Independence,
Kansas to Denver, Colorado and shares office space with Benson Mineral Group,
Inc. (BMG). In connection with that move, the Company entered into a cost and
expense sharing agreement with BMG, a privately held Oklahoma corporation. The
Company's current president is also the president, a director and sole
shareholder of BMG. Pursuant to the cost and expense sharing agreement, the
Company has agreed to compensate BMG for office rent, personnel costs and other
overhead and administrative expenses associated with operation of its business
based upon actual use of the facilities and personnel by the Company. During the
year ended December 31, 1999, the Company paid or accrued $230,830 to BMG
pursuant to this arrangement, of which $14,878 was payable at December 31, 1999.
During the year ended December 31, 1998, the Company paid or accrued $660,646 to
BMG pursuant to this arrangement, of which $47,379 was payable at December 31,
1998. Since July 1998, the Company has not paid any significant amount of rent
to BMG because the Company has leased its own office space. At the end of
February 1999, all BMG employees were transferred to the Company's payroll. The
Company billed BMG $346,127 in 1999 for time spent by Company employees on
business affairs of BMG, which has been netted against general and
administrative expenses in the accompanying statement of operations. The cost
and expense sharing agreement is effective so long as the current president
functions in such capacity.
In addition, the Company entered into an executive employment agreement with its
current president dated August 7, 1997. The agreement provides for a base salary
of not less than $150,000 per year and bonuses at the discretion of the Board of
Directors. It has an initial term of three years, but renews automatically for
successive one-year terms unless terminated by either party. The agreement also
provides for the granting of options
F-10
<PAGE> 48
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
3. RELATED PARTY TRANSACTIONS (CONTINUED)
to purchase shares of the Company's common stock (see Note 11). During the third
quarter of 1999, the current president drew no salary.
The three outside directors of the Company's Board of Directors each received
3,879 shares of the Company's common stock in 1999 as payment for directors fees
earned from April 1, 1998 through December 31, 1998, and each outside director
received 9,600 shares of the Company's common stock in 2000 for directors' fees
earned in 1999.
The Company is a participating employer of a multi-employer profit sharing plan
sponsored by BMG and has contributed $56,893 and $34,190 for the years 1999 and
1998, respectively.
4. OIL AND GAS PROPERTIES
The Company's oil and gas activities are conducted within the continental United
States. The following schedules present capitalized costs at December 31, 1999
and 1998 and results of operations for producing activities for the years ended
December 31, 1999 and 1998. At December 31, 1999 and 1998, costs associated with
acquisition and development activities of $53,353,560 and $51,133,433,
respectively, are considered evaluated and subject to amortization.
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
Capitalized costs:
Oil and gas properties $ 53,353,560 $ 51,133,433
Accumulated depreciation, depletion
amortization and valuation allowance 28,633,515 25,966,663
------------ ------------
Net capitalized costs $ 24,720,045 $ 25,166,770
============ ============
Results of operations for producing activities:
Oil and gas sales $ 7,144,849 $ 4,376,561
Production costs (2,792,146) (2,692,644)
Depreciation, depletion and amortization (2,666,843) (3,669,802)
Full-cost pool valuation allowance -- (15,206,978)
------------ ------------
Results of operations from producing activities
(excluding overhead expenses) $ 1,685,860 $(17,192,863)
============ ============
</TABLE>
F-11
<PAGE> 49
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
4. OIL AND GAS PROPERTIES (CONTINUED)
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
----------- -----------
<S> <C> <C>
Amortization per equivalent physical unit (barrels)
of production (excludes full-cost pool
valuation allowance) $ 5.13 $ 8.91
========== ==========
</TABLE>
Costs incurred in oil and gas acquisition and development activities are as
follows:
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
----------- -----------
<S> <C> <C>
Property acquisition costs $ -- $39,559,220
Development costs 2,970,127 1,583,158
----------- -----------
$ 2,970,127 $41,142,378
=========== ===========
</TABLE>
Capitalized costs are subject to an annual test of recoverability by comparison
to the present value of future net revenues from proved reserves. Any
capitalized costs in excess of the present value of future net revenues are
required to be expensed. At December 31, 1998, capitalized costs exceeded the
present value of future net revenues by $15,206,978, which resulted in a
write-down of the carrying value of the oil and gas properties.
For the year ended December 31, 1998, the primary reasons for the write-down of
the carrying value of the oil and gas properties were: (1) lower oil and gas
prices at December 31, 1998, (2) higher than originally anticipated operating
and capital costs on the properties acquired from Union Pacific Resources
Company (UPR), (3) the inability to establish for the purposes of year-end
reserve estimates the extent of the Company's interest in certain formations
within the UPR properties and (4) predictability of production from the Dakota
formation of the UPR properties less than originally anticipated.
F-12
<PAGE> 50
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
5. NATURAL GAS GATHERING SYSTEMS
Natural gas gathering systems consisted of the following:
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
----------- -----------
<S> <C> <C>
Kansas systems - cost $ 2,584,717 $ 2,432,096
Accumulated depreciation and valuation allowance (1,635,488) (1,455,046)
----------- -----------
$ 949,229 $ 977,050
=========== ===========
</TABLE>
6. EQUIPMENT AND LEASEHOLD IMPROVEMENTS
Equipment and leasehold improvements consisted of the following:
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
----------- -----------
<S> <C> <C>
Leasehold improvements $ 98,307 $ 5,013
Oil field equipment 238,689 238,689
Autos and trucks 73,242 121,180
Office equipment and furniture 242,388 210,260
----------- -----------
652,626 575,142
Accumulated depreciation (338,965) (280,096)
----------- -----------
$ 313,661 $ 295,046
=========== ===========
</TABLE>
7. LAND HELD FOR RESALE
The Company owns land located in Ingleside, Texas, which it acquired in July
1994. Until 1998, a refinery was located on 20 acres of the approximately 100
acres of undeveloped real estate.
The refinery had been nonoperational since the early 1980s and marketing efforts
for the refinery were unsuccessful. Management decided to dismantle and salvage
the refinery and sell the real estate, writing down the refinery and land to a
net realizable value of $700,000 by recognizing an impairment loss of $1,075,011
in 1997. During 1998, the Company spent approximately $145,000 to dismantle the
refinery, but concluded that the net realizable value of the land was still
approximately $700,000. This resulted in an additional impairment loss of
approximately $145,000 for the year ended December 31, 1998. The Company had no
offers for the land during 1999; accordingly, the Company recorded an additional
impairment of $400,000 for the year ended December 31, 1999.
F-13
<PAGE> 51
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
8. PIPELINE LEASE
The Company leases and operates a 72-mile gas pipeline under an operating lease
which was acquired for a total cost of $707,308. The lease expires January 31,
2008 and requires minimum monthly payments of $6,500 per month. A volume rent
adjustment is computed at each six-month anniversary date. The recomputed
monthly rent is equal to the average monthly volume transported through the
pipeline during the previous six months, in thousands of cubic feet (MCF),
multiplied by $.08. The monthly rent charge may not be less than $6,500 and may
not exceed $13,600. Average monthly MCFs transported during any six month period
during the years ended December 31, 1999 and 1998 did not result in any volume
rent adjustments. The agreement includes a purchase option for $1,800,000 which
can be exercised at any time during the term of the lease.
9. INCOME TAXES
The tax effects of temporary differences that give rise to deferred tax assets
and liabilities are as follows:
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
Deferred tax liabilities:
Purchase accounting adjustment - book basis of
acquired assets greater than tax basis - lease
equipment $ -- $ 176,377
Deferred tax assets:
Net operating loss carryforwards 10,754,705 6,615,199
Oil and gas properties - full-cost pool amortization
greater than tax depletion 3,548,249 6,611,637
Depreciation on equipment 327,296 328,518
------------ ------------
14,630,250 13,555,354
Less valuation allowance (14,630,250) (13,378,977)
------------ ------------
-- 176,377
------------ ------------
Net deferred amount $ -- $ --
============ ============
</TABLE>
The valuation allowance was increased by $1,251,273 and $9,161,759 at December
31, 1999 and 1998, respectively, to reduce the deferred tax asset to zero.
F-14
<PAGE> 52
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
9. INCOME TAXES (CONTINUED)
The Company's net operating loss carryforwards are subject to IRC Section 382
limitations. The Company may use, in any one tax year, up to $507,000 of net
operating losses from carryforwards expiring in years through 2008 and up to
$2,285,000 of net operating losses from carryforwards expiring in 2009 and 2010.
The net operating loss carryforwards available to United States Exploration,
Inc. for income tax purposes are as follows:
<TABLE>
<CAPTION>
EXPIRATION DATES
----------------
<S> <C>
2002 $ 868,000
2003 2,545,000
2004 1,300,000
2005 293,000
2006 448,000
2007 37,000
2008 2,162,000
2009 537,000
2010 435,000
2011 301,000
2012 1,499,000
2018 7,182,000
2019 10,694,000
-----------
$28,301,000
===========
</TABLE>
10. MAJOR CUSTOMERS
The Company sold substantially all of its produced and purchased gas to three
purchasers for the year ended December 31, 1999 and to six purchasers for the
year ended December 31, 1998. The Company sold substantially all of its oil to
three purchasers for the year ended December 31, 1999 and to five purchasers for
the year ended December 31, 1998.
F-15
<PAGE> 53
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
11. STOCK OPTION PLANS
The Company has elected to follow APB 25 and related interpretations in
accounting for its employee stock options because, as discussed below, the
alternative fair value accounting provided for under Statement of Financial
Standards No. 123, Accounting for Stock-Based Compensation (SFAS 123), requires
use of option valuation models that were not developed for use in valuing
employee stock options. Under APB 25, because the exercise price of the
Company's employee stock options equals the market price of the underlying stock
on the date of grant, no compensation expense is recognized.
On May 5, 1999, the Company adopted the 1999 Employee Stock Option Plan (the 99
Plan) and reserved a total of 500,000 common shares for issuance. Options
granted may be Incentive Stock Options or Non-Statutory Options at the
discretion of a committee of the Board of Directors. All options must be granted
within 10 years from May 5, 1999. At December 31, 1999, no options have been
granted under the 99 Plan.
Effective January 13, 1989, the Company adopted an Incentive Stock Option Plan
(the Plan) and reserved a total of 1,000,000 common shares for issuance. The
Plan expired on January 13, 1999 and no new options can be granted. All options
granted prior to the expiration remain outstanding until they have expired or
been canceled.
Effective May 25, 1990, the Board of Directors adopted a Nonqualifying Stock
Option Plan (NQSOP) for the benefit of nonemployee directors of the Company and
others having rendered significant services to the Company. To date, an
aggregate of 2,900,000 common shares is reserved to be issued pursuant to the
NQSOP. As of December 31, 1999 and 1998, there were 179,200 options available
for issuance. The NQSOP is administered at the discretion of the compensation
committee of the Board of Directors. Unless otherwise specified, the options
expire 10 years from the date of the grant. The NQSOP will expire May 25, 2000.
In August 1997, the Company entered into an employment agreement with its
current president which provided for the issuance of nonqualified stock options.
A total of 4,000,000 options were issued with 1,000,000 shares each being
exercisable at $4.50, $6.00, $9.00 and $12.00 per share. By August 1998, all
options were exercisable. The options have a 10-year life.
F-16
<PAGE> 54
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
11. STOCK OPTION PLANS (CONTINUED)
A summary of the Company's stock option plans as of December 31, 1999 and 1998
is presented below. No compensation expense related to stock options granted in
1998 was recorded as the option exercise prices were greater than the fair
market value on date of grant.
<TABLE>
<CAPTION>
WEIGHTED AVERAGE
SHARES EXERCISE PRICE
--------- --------------
<S> <C> <C>
Outstanding at December 31, 1997 4,632,000 $7.34
Granted 225,600 4.00
Expired (40,000) 3.00
---------
Outstanding at December 31, 1998 4,817,600 7.22
Granted -- --
Expired (50,200) 3.63
---------
Outstanding at December 31, 1999 4,767,400 7.25
=========
Options exercisable at December 31, 1998 4,577,000 7.39
=========
Options exercisable at December 31, 1999 4,633,800 7.35
=========
</TABLE>
Options outstanding at December 31, 1999 have exercise prices ranging from $2 to
$12 with a weighted-average contractual life of 7.73 years. They are summarized
as follows:
<TABLE>
<CAPTION>
EXERCISE REMAINING
SHARES PRICE LIFE
- ---------- ----------- --------------
<S> <C> <C>
30,000 $ 2.00 4.42 years
737,400 4.00-4.25 7.66-8.5 years
1,000,000 4.50 7.66 years
1,000,000 6.00 7.66 years
1,000,000 9.00 7.66 years
1,000,000 12.00 7.66 years
- ----------
4,767,400
==========
</TABLE>
F-17
<PAGE> 55
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
11. STOCK OPTION PLANS (CONTINUED)
Pro forma information regarding net income and earnings per share is required by
SFAS 123, and has been determined as if the Company had accounted for its
employee stock options under the fair value method of that statement. The fair
value for these options was estimated at the date of grant using the
Black-Scholes option pricing model. There were no options granted during 1999.
With respect to the options granted during 1998, a risk-free interest rate of
5.25%, a dividend yield of 0%, a volatility factor of .63, and a
weighted-average expected life of five years were applied.
For purposes of pro forma disclosures, the estimated fair value of the options
is amortized to expense over the options' vesting period. The Company's pro
forma net loss and net loss per share for the year ended December 31, 1999 and
December 31, 1998 are as follows:
<TABLE>
<CAPTION>
1999 1998
-------------- --------------
<S> <C> <C>
Net loss--as reported $ (4,054,803) $ (21,251,173)
Net loss--pro forma (4,200,519) (24,623,587)
Basic loss per common share - as reported (0.27) (1.67)
Basic loss per common share - pro forma (0.28) (1.93)
Weighted average fair value of options granted
during the period -- 1.81
</TABLE>
12. SERIES C CONVERTIBLE PREFERRED STOCK
In late 1996, the Company completed a private placement of 4,000,000 shares of
Series C Convertible Preferred Stock (Series C Preferred Stock) at $6.00 per
share. Total proceeds received were $24,000,000. The stock carries an 8%
cumulative per annum dividend and is convertible at the option of the holder
into two shares of Company common stock for each share of Series C Preferred
Stock. This conversion rate is subject to adjustment for common stock dividends,
additional common stock issuances, or any stock rights and warrant issuances.
The Series C Preferred Stock has a liquidation preference of $6.00 per share,
plus accrued and unpaid dividends. The Company may redeem the stock at the price
of $6.00 per share plus accrued and unpaid dividends.
F-18
<PAGE> 56
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
12. SERIES C CONVERTIBLE PREFERRED STOCK (CONTINUED)
During 1999 and 1998, 50,000 and 3,341,834 shares of Series C Preferred Stock
were converted into 100,000 and 6,683,668 shares of common stock, respectively,
leaving 443,166 and 493,166 shares of Series C Preferred Stock outstanding on
December 31, 1999 and 1998, respectively. Dividends were declared and paid for
the first two quarters of 1998. No dividends have been declared during 1999 or
the last two quarters of 1998. Cumulative dividends applicable to 1999 and 1998
are $319,080 and $106,360, respectively.
Under the terms of the Series C Preferred Stock, if dividends have not been paid
in an amount equal to at least six quarterly dividends, the number of directors
on the Company's board is automatically increased by two and the holders of the
Series C Preferred Stock are entitled to elect the two new directors. The
Company is obligated to call a meeting of the holders of the Series C Preferred
Stock for the purpose of electing those directors upon the written request of
the holders of two-thirds of the outstanding shares of Series C Preferred Stock.
Upon payment of the dividend arrearage, the size of the board is reduced by two
and the terms of the directors elected by the holders of the Series C Preferred
Stock automatically terminate. On December 31, 1999, the right of the holders
arose.
If dividends are not paid on the Series C Preferred Stock for three successive
years, the Company may pay all dividends in arrears with shares of its common
stock, subject to the consent of the holders of the Series C Preferred Stock.
Such consent may not be withheld for more than 180 consecutive days.
13. ACQUISITIONS
On May 15, 1998, the Company acquired from Union Pacific Resources Company
(UPR), all of UPR's working interests in producing oil and gas wells in 34 oil
and gas fields in the Wattenberg area of the Denver-Julesburg Basin in
northeastern Colorado. The purchase price for the wells, as adjusted, was
approximately $39,560,000. Included in accounts receivable at December 31, 1998
is $1,686,118 due from UPR as a final settlement of the purchase price. At the
closing of the acquisition, the Company also entered into an exploration
agreement (Exploration Agreement) with UPR giving the Company the right to
explore and develop all of UPR's undeveloped acreage in the area, excluding
certain acreage already committed to other agreements.
F-19
<PAGE> 57
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
13. ACQUISITIONS (CONTINUED)
The Exploration Agreement covers approximately 400,000 gross acres and will also
cover any undeveloped acreage currently committed to another agreement that
reverts to UPR during its term. In order to keep the Exploration Agreement in
effect, the Company drilled 15 commitment wells during the first 18 months
ending on November 30, 1999 and is required to drill an additional 20 commitment
wells during each succeeding 12-month period for up to a maximum of five
12-month option periods. If the Company does not drill the required number of
commitment wells during any period, the Exploration Agreement will terminate at
the end of the period and the Company will be required to pay liquidated damages
of $125,000 for each commitment well that was not drilled during the period. The
Company fulfilled its commitment well obligations during the 18 months ended
November 30, 1999.
14. FAIR VALUE OF FINANCIAL INSTRUMENTS
Statement of Financial Accounting Standards No.107, Disclosures About Fair Value
of Financial Instruments, requires that the Company disclose estimated fair
values for its financial instruments. Such information is based on the
requirements set forth in that Statement and does not purport to represent the
aggregate net fair value of the Company. The fair values of the Company's
financial instruments, consisting of cash and cash equivalents and borrowings
under the credit facility, are considered to approximate their carrying amounts
in the Company's balance sheet. In arriving at this determination, no
consideration has been given to the adequacy of the underlying collateral on the
credit facility.
F-20
<PAGE> 58
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
15. COMMITMENTS
The Company entered into a 117 month lease, effective July 1, 1998, for office
space. Approximately 12,000 square feet were leased with monthly payments of
$14,817 for the first 57 months and $19,411 for the remainder of the lease term.
The Company has incurred costs of approximately $100,000 for leasehold
improvements, substantially all of which were incurred during 1999. The
approximate minimum aggregate rental commitment under the office space lease is
as follows:
<TABLE>
<S> <C>
2000 $ 177,804
2001 177,804
2002 177,804
2003 219,150
2004 232,932
Thereafter 757,029
----------
$1,742,523
==========
</TABLE>
See Note 8 for additional commitments under a gas pipeline lease agreement.
The Company committed to drill 20 wells by November 30, 2000 under the
Exploration Agreement which is a part of the acquisition of properties from UPR
(see Note 13). Liquidated damages of $125,000 per commitment well not drilled
will be due UPR, resulting in a total of $2,500,000 if no commitment wells are
drilled by November 30, 2000.
F-21
<PAGE> 59
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
16. ASSETS HELD FOR SALE
On January 20, 1999, the Company sold, effective as of December 31, 1998, the
stock of three wholly owned subsidiaries. Performance Petroleum Corporation and
Pacific Osage, Inc. were sold in one transaction for $650,000. United States Gas
Gathering Co., Inc. was sold in another transaction for $1,175,000. As required
by the Company's credit agreement with its lender, proceeds were used to reduce
the Company's borrowings. The underlying properties sold consisted of the
following:
<TABLE>
<S> <C>
Current assets $ 134,542
Natural gas gathering systems, net 371,622
Oil and gas property and equipment, net 1,159,076
Building and other equipment, net 218,203
-----------
1,883,443
Current liabilities (58,443)
-----------
$ 1,825,000
===========
</TABLE>
17. CREDIT AGREEMENT
In connection with the acquisition of the UPR properties, the Company entered
into a credit agreement with ING (U.S.) Capital Corporation establishing a
revolving credit facility (the Credit Agreement). The maximum available
borrowings under the Credit Agreement were initially set at $35 million, subject
to periodic redeterminations of the borrowing base. The Company initially
borrowed $29 million under the Credit Agreement to pay a portion of the purchase
price of the UPR properties, and the balance was paid with the Company's
existing funds. Principal is repayable in 20 quarterly installments beginning
March 31, 2000. Interest is generally payable on a quarterly basis at a rate,
selected by the Company, which is determined by reference to LIBOR or the
lender's reference rate plus varying margins. The Company is in default of
scheduled interest payments, and, effective October 1, 1999, interest was
payable at a default rate. Under the default provisions, interest accrues on
unpaid interest. At December 31, 1999, the outstanding loan balance of $31.25
million ($31.9 million, 1998), plus unpaid accrued interest, bore interest at a
rate of 11.25% (varying from 7.6875% to 8.5%, 1998) per annum. The obligations
of the Company under the Credit Agreement are secured by substantially all of
the Company's oil and gas properties. The Credit Agreement prohibits the payment
of dividends on Common Stock and prohibits the payment of dividends on the
Series C Preferred Stock for periods ending after June 30, 1999. Prior to June
30, 1999, no dividend could be paid on the Series C Preferred Stock if a default
under the Credit Agreement existed or would exist after the payment.
F-22
<PAGE> 60
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
17. CREDIT AGREEMENT (CONTINUED)
Since September 30, 1998, the Company has not met certain financial ratios and
net worth requirements contained in the Credit Agreement. The Credit Agreement
requires the Company to have a ratio of EBITDA (Earnings Before Interest, Taxes,
Depreciation and Amortization) to interest expense of not less than 2.75:1, to
have a ratio of current assets to current liabilities of not less than 1:1, and
to maintain tangible net worth of at least $20 million.
As a result of the Company's failure to meet these ratios, requirements, and
scheduled interest payments at December 31, 1999, the loan is in default. On
March 28, 2000, the bank gave the Company official notice of acceleration and of
its intention to proceed with foreclosure. Accordingly, the Company is required
by generally accepted accounting principles to classify the entire $31,250,000
due to the lender as a current liability even though the loan is payable by its
terms over a five-year period beginning March 31, 2000 as follows:
<TABLE>
<S> <C>
2000 $ 8,000,000
2001 7,500,000
2002 7,000,000
2003 7,000,000
Thereafter 1,750,000
-----------
$31,250,000
===========
</TABLE>
The Company has not yet established with the bank a plan for eliminating its
defaults under the Credit Agreement. However, the Company is in discussions with
the bank and is evaluating its options.
F-23
<PAGE> 61
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
18. OIL AND GAS INFORMATION (UNAUDITED)
The estimates of the Company's proved oil and gas reserves are based upon
evaluations prepared by independent petroleum engineers as of December 31, 1999
and 1998. All reserves are located within the United States. Reserves are
estimated in accordance with guidelines established by the Securities and
Exchange Commission and the Financial Accounting Standards Board, which require
that reserve estimates be prepared under existing economic and operating
conditions with no provision for price and cost escalation except by contractual
arrangements. Proved reserves are estimated quantities of oil and natural gas
which geological and engineering data demonstrate with reasonable certainty to
be recoverable in future years from known reserves. Proved developed reserves
are those which are expected to be recovered through existing wells with
existing equipment and operating methods. Reserves are stated in barrels of oil
and millions of cubic feet of natural gas.
<TABLE>
<CAPTION>
DECEMBER 31
----------------------------------------------------------
1999 1998
-------------------------- --------------------------
Oil Gas Oil Gas
(bbls) (mmcf) (bbls) (mmcf)
---------- ---------- ---------- ----------
<S> <C> <C> <C> <C>
Proved developed and
undeveloped reserves,
beginning of period 2,215,640 58,971 252,215 2,518
Revisions of previous estimates 380,478 (1,209) 7,556 (21)
Extensions and discoveries 38,000 1,719 -- --
Production (107,595) (2,471) (140,112) (1,650)
Purchase of minerals in place -- -- 2,238,422 58,863
Dispositions of minerals
in place (Note 16) (46,182) (262) (142,441) (739)
---------- ---------- ---------- ----------
Proved developed and
undeveloped reserves,
end of period 2,480,341 56,748 2,215,640 58,971
Proved developed reserves:
Beginning of period 717,419 23,237 207,202 1,565
End of period 1,383,698 27,018 717,419 23,237
</TABLE>
F-24
<PAGE> 62
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
18. OIL AND GAS INFORMATION (UNAUDITED) (CONTINUED)
Geological and engineering estimates of proved oil and gas reserves at one point
in time are highly interpretive, inherently imprecise and subject to ongoing
revisions that may be substantial in amount. Although every reasonable effort is
made to ensure that the reserve estimates reported represent the most accurate
assessments possible, these estimates are by their nature generally less precise
than other estimates presented in connection with financial statement
disclosures.
The following schedules present the standardized measure of estimated discounted
future net cash flows from the Company's proved reserves and an analysis of the
changes in these amounts for the periods indicated. Estimated future cash flows
are determined by using period-end prices for December 31, 1999 and 1998
adjusted only for fixed and determinable increases in natural gas prices
provided by contractual agreements. Estimated future production and development
costs are based on economic conditions at December 31, 1999 and 1998. The
standardized measure of future net cash flows was prepared using the prevailing
economic conditions existing at December 31, 1999 and 1998, and such conditions
continually change. Accordingly, such information should not serve as a basis
for making any judgment on the potential value of recoverable reserves or in
estimating future results of operations.
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
RELATING TO PROVED RESERVES (UNAUDITED)
<TABLE>
<CAPTION>
DECEMBER 31
1999 1998
------------- -------------
<S> <C> <C>
Future cash inflows $ 188,555,098 $ 129,807,936
Future production and development costs (102,074,575) (71,530,056)
------------- -------------
Future net cash flows 86,480,523 58,277,880
10% annual discount for estimated timing of
cash flows (47,262,546) (33,111,110)
------------- -------------
Standardized measure of discounted future
net cash flows $ 39,217,977 $ 25,166,770
============= =============
</TABLE>
F-25
<PAGE> 63
United States Exploration, Inc. and Subsidiaries
Notes to Consolidated Financial Statements (continued)
18. OIL AND GAS INFORMATION (UNAUDITED) (CONTINUED)
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31
1999 1998
------------ ------------
<S> <C> <C>
Amount at beginning of period $ 25,166,770 $ 3,390,640
Sales of minerals in place (750,000) (860,754)
Sales and transfers of oil and gas production,
net of production costs (4,352,703) (1,683,918)
Development costs incurred 2,970,127 --
Revisions of previous quantity estimates, net
of changes in previous estimates of development
and production costs and timing revisions 2,147,655 --
Extensions and discoveries 2,198,064 --
Purchase of minerals in place -- 25,950,822
Accretion of discount 2,516,677 --
Net changes in prices and production costs 8,647,878 (1,630,020)
Other 673,509 --
------------ ------------
14,051,207 21,776,130
------------ ------------
Amount at end of period $ 39,217,977 $ 25,166,770
============ ============
</TABLE>
F-26
<PAGE> 64
EXHIBIT INDEX
<TABLE>
<CAPTION>
EXHIBIT DOCUMENT DESCRIPTION
<S> <C>
10.22 Agreement for Release and Termination dated November 20,
1999, by and among the Company, Kinder Morgan, Inc.,
formerly KN Energy, Inc., HS Resources, Inc. and
Resource Gathering Systems, Inc.
23.1 Consent of Ernst & Young LLP, independent certified
public accountants, to incorporation of this report by
reference into the Company's Registration Statement on
Form S-8 (Registration No. 333-60983).
24 Powers of Attorney.
27 Financial Data Schedule.
</TABLE>
<PAGE> 1
EXHIBIT 10.22
AGREEMENT FOR RELEASE AND TERMINATION
This Agreement for Release and Termination (this "Agreement")
is entered into on this 20th day of November, 1999, by and among United States
Exploration, Inc. ("UXP"), Kinder Morgan, Inc., formerly KN Energy, Inc.
("KMI"), HS Resources, Inc. ("HSR"), and Resource Gathering Systems, Inc.
("RGSI"), collectively referred to herein as the "Parties" and individually as a
"Party".
WHEREAS, pursuant to paragraph 3 of that certain letter
agreement dated July 30, 1991, between KN Energy, Inc. ("KNE") and Union Pacific
Resources Company ("UPRC'), referred to herein as the "July 30, 1991 Letter
Agreement", KNE granted to UPRC a right of first refusal to purchase any or all
of the Wattenberg Gas Gathering System (the "System") and a right to approve any
new operator or takeover of operatorship of the System under the circumstances
described therein, such rights collectively referred to herein as the "Right of
First Refusal";
WHEREAS, pursuant to an Assignment of Right of First Refusal
dated October 20, 1999, UPRC assigned and conveyed the Right of First Refusal to
UXP;
WHEREAS, KMI wishes to sell to HSR and HSR wishes to purchase
from KMI the System; and,
WHEREAS, KMI and HSR agree to grant certain benefits and
rights to UXP in return for UXP's waiver, release, and termination of the Right
of First Refusal:
NOW, THEREFORE, in consideration of the mutual benefits to be
derived herein, the Parties agree as follows:
1. CONDITION SUBSEQUENT: This Agreement shall
terminate if on or before December 31, 1999, HSR and KMI, do
not enter into a definitive agreement for the purchase and
sale of KMI's Wattenberg Gas Gathering System upon such terms
and conditions, exceptions and reservations as KMI and HSR
shall determine in their sole and unfettered judgment, there
being no obligation on the part of either such party to enter
into such definitive agreement. This condition referred to
hereinafter as the "Condition Subsequent".
2. WAIVER, RELEASE, AND TERMINATION AGREEMENT: KMI
and UXP agree to enter into the Waiver, Release, and
Termination Agreement attached hereto as Exhibit "A", by
reference made a part hereof, upon entering into this
Agreement.
3. COPAS OVERHEAD RATES: HSR and UXP agree to amend
the COPAS drilling and producing overhead rates under
operating agreements currently in effect
<PAGE> 2
whereunder HSR is the operator and UXP is the non-operator
(the "Operating Agreements") which shall affect overhead rates
charged on presently existing wells and future wells drilled
thereunder. Effective November 1, 1999, and for a period of
ten (10) years thereafter, the drilling and producing overhead
rates under the Operating Agreements shall be $5,000.00 and
$500.00 per month per well (to the 8/8ths interest),
respectively. After such ten-year period, the COPAS overhead
rates for all wells under the Operating Agreements shall be
subject to future escalation in accordance with the applicable
operating agreement.
4. UPRC/HSR EXPLORATION AGREEMENT: HSR and UPRC are
parties to that certain Exploration Agreement dated June 27,
1994 (the "Exploration Agreement"). UPRC has leased and
assigned certain interests to UXP which are subject to the
Exploration Agreement, and UPRC and UXP have entered into a
separate agreement whereby UPRC must offer to UXP any working
interest which may be available to UPRC under the Exploration
Agreement. Accordingly, HSR agrees to the following:
a. CONFIDENTIALITY PROVISIONS: HSR hereby
waives the confidentiality provisions in the
Exploration Agreement insofar, and only insofar, as
will allow UPRC to disclose any information, except
seismic, non-public and interpretative information,
to UXP which UPRC is entitled to receive from HSR
under the Exploration Agreement and affects any of
the interests UXP previously has acquired from UPRC,
or which will allow UXP to make an informed decision
whether it wishes to participate for UPRC's interest
in any well under which UPRC has the option to
participate pursuant to the Exploration Agreement and
which must be offered to UXP. HSR shall provide such
information not presently in UPRC's possession
directly to UXP.
b. Promptly upon entering into this
Agreement, HSR agrees to provide UXP with a list of
the acreage which currently is subject to the
Exploration Agreement.
5. RESOURCE GATHERING SYSTEMS, INC.: Resource
Gathering Systems, Inc. ("RGSI") is an affiliate of HSR, which
owns a mini-gathering system in the Wattenberg Field and
currently charges UXP $0.05/Mcf for gas gathered on its
system. RGSI agrees as follows:
a. GATHERING FEE: Effective October 1, 1999,
RGSI agrees to discontinue the $0.05/Mcf fee charged
to UXP for any gas gathered in presently existing
wells or future wells, which are on properties
currently owned, which are, or will be, connected to
the RGSI mini-gathering system as it exists today or
as expanded in the future.
- 2 -
<PAGE> 3
b. WELL CONNECTION COSTS: If HSR decides to
have RGSI gather gas from an HSR-operated well in
which UXP owns a working interest, HSR shall give UXP
notice of its plans and the estimated costs required
to have RGSI connect such well. If UXP decides to
have RGSI gather UXP's share of gas from such well,
UXP agrees to bear its proportionate share of the
costs to connect such well to the RGSI system, based
on its working interest in such well. Notwithstanding
the foregoing, HSR agrees that it shall bear the
entire cost to connect any of the following wells to
the RGSI mini-gathering system:
Dechant UPRR 41-1A
NE/NE Section 1-2N-65W
Ludwig UPRR 32-1 #2A
SW/NE Section 1-3N-66W
6. SEGREGATION OF UNITS ESTABLISHED FOR THE J-SAND
AND DAKOTA FORMATIONS: HSR and UXP shall use their reasonable,
diligent and good faith efforts to segregate some or all of
their jointly owned properties in the D-J Basin. HSR and UXP
shall devote such time, effort and personnel to the process as
may be needed in order for each to make a comprehensive
proposal to the other for such segregation, and to fairly
consider and respond to any proposals made by the other. HSR
shall make UXP a proposal for segregation by the last day of
February 2000. The terms of any proposal shall be entirely
within the discretion of the proposing party and the response
thereto exclusively within the discretion of the responding
party. Neither HSR nor UXP shall have any obligation to accept
any proposal of the other party, and no obligation to
segregate or exchange properties shall exist unless and until
HSR and UXP enter into and execute a written definitive
agreement to do so. The obligations under this paragraph 6
shall terminate December 31, 2000.
7. AMENDMENT TO THE GATHERING AGREEMENT: KMI agrees
to enter into and execute, and agrees to cause its subsidiary,
KN Gas Gathering, Inc. ("KNGG"), to enter into and execute the
Amendment of Gas Gathering Agreement (the "Gathering
Amendment") attached hereto as Exhibit "B", by reference made
a part hereof, upon KMI's entering into this Agreement. UXP
also agrees to execute the Gathering Amendment upon entering
into this Agreement.
8. AMENDMENT TO THE TRANSPORTATION AGREEMENT: KM
agrees to cause its subsidiary, KN Wattenberg Transmission
Limited Liability Company ("KNWTLLC"), to enter into and
execute the Amendment of Interruptible Transportation Service
Agreement ("Transportation Amendment") attached hereto as
Exhibit "C", by reference made a part hereof, upon KMI's
entering into this
- 3 -
<PAGE> 4
Agreement. UXP also agrees to execute the Transportation
Amendment upon entering into this Agreement.
9. AMENDMENT TO THE AGENCY AGREEMENT: KN Front Range
Gathering Company, now KNGG, as Agent, and UPRC, as Principal,
entered into that certain Agency Agreement dated March 29,
1993 (the "Agency Agreement"). UPRC assigned certain interests
to UXP which are subject to the Agency Agreement. KMI agrees
to cause its subsidiary, KNGG, to enter into and execute the
Amendment of Agency Agreement ("Agency Amendment") attached
hereto as Exhibit "D", by reference made a part hereof, upon
KMI's entering into this Agreement. UXP also agrees to execute
the Agency Amendment upon entering into this Agreement.
10. AMENDMENT TO DEVELOPMENT AGREEMENT: HSR and UXP
entered into that certain Development Agreement dated October
1, 1998, as amended, (the "Development Agreement") which
provides for the deepening of those wells listed on an exhibit
attached thereto. Promptly upon satisfaction of the Condition
Subsequent, HSR and UXP agree as follows:
a. WELLBORE REIMBURSEMENT COSTS: Effective
October 1, 1999, the Development Agreement shall be
amended by eliminating any requirement to pay a
Wellbore Reimbursement Cost as contained therein. HSR
and UXP further agree that even after the Development
Agreement terminates no Wellbore Reimbursement Cost
will be charged on any of the wells described on
Exhibit A of the Development Agreement, which were
not deepened during the term of the Development
Agreement and which either HSR or UXP proposes to the
other party to deepen in the future.
b. TERM OF DEVELOPMENT AGREEMENT: The term
of the Development Agreement will expire on October
1, 2000. UXP and HSR agree to extend the term of the
Development Agreement to October 1, 2001.
11. USE OF WELLBORES FOR SHALLOW OPERATIONS: New
provisions shall be added to Section 4 of the Development
Agreement to provide that if either HSR or UXP (the "Owning
Party") owns or controls 100% of the interest in a target
Shallow Zone in a well described on Schedule III (a "Joint
Well") which the other party operates, and the Owning Party
desires to conduct Shallow Operations in the subject wellbore,
it shall be deemed that an Approved Operation was conducted
for purposes of Section 4 in that well. If the Owning Party is
the operator of the well, it shall allow the other party to
temporarily take over operations on the subject wellbore and
to conduct its proposed Shallow Operations until complete, but
subject to the other requirements of Section 4; provided,
however, that if a third party has an ownership interest in
the subject wellbore, the Owning Party's proposal to conduct a
Shallow Operation shall not commence until and unless the
Owning Party obtains the consent
- 4 -
<PAGE> 5
of such third party for the proposed Shallow Operations in the
subject wellbore. This provision shall survive the termination
of the Development Agreement.
12. OPERATING AGREEMENTS: With respect to any well
which HSR operates in the D-J Basin that UXP determines is no
longer producing in paying quantities for UXP's account, UXP
shall have the right to give HSR written notice that UXP
desires to surrender its entire interest in the currently
producing formation(s), limited to the wellbore only, to HSR
in exchange for HSR assuming UXP's proportionate share of the
plugging and abandonment costs and liabilities attributable to
such interests; provided, however, that HSR shall not have the
obligation to assume such cost obligations or liabilities if
HSR agrees to plug and abandon the affected formation(s)
following receipt of UXP's written notice in accordance with
the terms of the applicable operating agreement. If HSR elects
to assume UXP's plugging and abandonment costs and liabilities
which UXP desires to surrender, and if HSR subsequently
desires to deepen or recomplete the subject well to a
formation which UXP has retained an ownership interest, UXP
shall have the right to participate for its proportionate
share of the costs to deepen or recomplete the subject well,
all in accordance with the terms of the applicable operating
agreement, provided that UXP shall not regain its interest in
the previously surrendered formation, UXP shall again become
liable for its share of plugging and abandonment costs and UXP
shall receive a share of equipment that it previously owned
equal to its working interest share of the new producing
formation.
13. LUDWIG #2-5 WELL: HSR and UXP agree to enter into
an operating agreement for the Ludwig #2-5 Well located in the
NW/4NW/4 of Section 5, Township 3 North, Range 65 West, Weld
County, Colorado, using substantially the same form of
operating agreement as affecting the Ludwig #1-5 Well located
in the NW/4NE/4 of the same section, except naming UXP as
operator, providing for "15%" in the blank on line 15 of page
two, correctly reflecting the parties interests on Exhibit
"A", and incorporating all of the amendments contained in this
Agreement. UXP shall prepare such operating agreement for
HSR's execution.
14. PRODUCTION INFORMATION: Promptly following
satisfaction of the Condition Subsequent, and continuing
thereafter, HSR shall provide to UXP on a daily basis the
estimated gross daily production volumes and on a monthly
basis copies of the Gas Metering Volume Statements for each
HSR-operated well in which UXP has a working interest. Such
information shall be the same information as used and relied
on by HSR. However, HSR does not represent, warrant, or
guaranty the accuracy or completeness of such production data.
UXP acknowledges that use of or reliance on such data shall be
at UXP's sole risk. HSR shall have no obligation to allocate
to or identify the various owners in such gross daily
production volumes for purposes of delivering such data to UXP
pursuant to this Agreement. Additionally, HSR agrees to
provide UXP with information contained in the reports filed
with the Colorado Oil
- 5 -
<PAGE> 6
and Gas Conservation Commission and affecting UXP/HSR jointly
owned wells which HSR operates.
15. GAS IMBALANCES: HSR estimates that as of August
31, 1999, gas production for the account of UXP (including the
Weld County Partnership production interests, subject to
True's consent) is under delivered on wells which HSR operates
in the D-J Basin in the aggregate amount of 175,000 MMBtu. HSR
hereby agrees to cash-out UXP's gas imbalance at a price of
$2.50 per MMBtu within fifteen (15) days of satisfaction of
the Condition Subsequent. The parties acknowledge that the
foregoing is based on HSR's statement of imbalance, and that
UXP and HSR shall have the opportunity to verify such amount.
UXP and HSR shall work diligently to arrive at a final
reconciliation by December 31, 1999. The final reconciliation
amount will be made at $2.50 per MMBtu.
16. POOLING AGREEMENTS: It may be necessary for UXP
and HSR to enter into pooling agreements to hold various
leases acquired by UXP from UPRC. HSR agrees to enter into
such pooling agreements upon UXP's request, using
substantially the same form of pooling agreement as attached
to the Development Agreement. The pooled area will be limited
to the Drilling Unit for the applicable formations in a
completed well. Drilling Unit is defined in Paragraph 5b of
the Development Agreement. In no event will the pooled area be
greater than 320 acres.
17. DAKOTA FARMOUT AGREEMENT: Promptly following
satisfaction of the Condition Subsequent, HSR and UXP agree to
enter into a Farmout Agreement covering the Dakota Formation
under the lands and wellbores identified on Schedule II
attached hereto, by reference made a part hereof. Under the
agreement, HSR shall grant to UXP the right to commence, on or
before December 31, 2000: (i) operations for the deepening to
the Dakota Formation in any of the eleven (11) wellbores
identified on Schedule II, and (ii) operations for the
recompletion of the Dakota Formation in any of the six (6)
wellbores identified on Schedule II. HSR will reserve a
non-convertible overriding royalty interest, proportionately
reduced, equal to the difference between leasehold burdens
existing as of the date of this Agreement and twenty percent
(20%). UXP is under no obligation to commence any of the
operations. The only loss for failure to conduct an operation
shall be the loss of any assignment pursuant hereto associated
with such operation. UXP shall take over operations of a well
to conduct the deepening or recompletion operation therein,
and return operations to HSR once UXP's operations are
completed. After UXP has recouped from the proceeds of all
production produced, sold, and allocated to the Dakota
Formation in a well, after deducting all burdens payable out
of production and all production taxes, 100% of the costs
incurred by UXP to either deepen or recomplete such well,
including operating costs during such recoupment period, HSR
shall backin for a twenty-five percent (25%) working interest,
proportionately reduced by HSR's original interest in the
Dakota Formation in such well. Payout
- 6 -
<PAGE> 7
shall be on a well-by-well basis. The allocation formula to be
used shall be the same formula as previously used under the
Development Agreement. The farmout shall contain such other
standard provisions as HSR and UXP reasonably require.
18. JOINT RECOMPLETION OF DAKOTA FORMATION: Promptly
following satisfaction of the Condition Subsequent, and
subject to title approval, HSR and UXP agree to participate
for their proportionate share in the recompletion of the
Dakota Formation in the five (5) wellbores identified on
Schedule 11 in accordance with the terms and conditions of the
Development Agreement, as amended herein. HSR shall promptly
issue to UXP a separate AFE for each well setting out the
reasonable costs to recomplete the Dakota Formation.
19. PRESS RELEASES AND PUBLIC ANNOUNCEMENTS: No Party
hereunder shall issue any press release or make any public
announcement relating to the subject matter of this Agreement
prior to the Condition Subsequent having been met without the
prior approval of the other Parties, which approval shall not
be unreasonably withheld; provided, however, that a Party may
make any public disclosure it believes in good faith is
required by applicable law or any listing or trading agreement
concerning its publicly traded securities (in which case the
disclosing Party will use its reasonable best efforts to
advise the other Parties prior to making the disclosure).
20. ENTIRE AGREEMENT: This Agreement, including the
exhibits attached hereto, constitutes the entire agreement
between the Parties with respect to the subject matter hereof
and supersedes all prior understandings, agreements, or
representations by, between, or among the Parties, written or
oral, with respect to such subject matter.
21. SECTION 29 TAX CREDIT ISSUE: HSR represents and
warrants that it has the authority to enter into this
agreement on behalf of those parties holding legal title under
any Section 29 Tax Credit Transaction.
22. SUCCESSORS: This Agreement shall be binding upon
and inure to the benefit of the Parties hereto and their
respective successors, assigns, subsidiaries, and affiliates.
23. GOVERNING LAW: This Agreement shall be governed
by and construed in accordance with the laws of the State of
Colorado without giving effect to any choice or conflict of
law provision or rule.
24. LEGAL FEES: The prevailing Party in any legal
proceeding brought under or to enforce this Agreement shall be
entitled to recover court costs and reasonable attorneys' fees
from the nonprevailing Party.
- 7 -
<PAGE> 8
25. FURTHER ASSURANCES: Each of the Parties will
execute, acknowledge, and deliver to the other such further
instruments and take such other actions, as may be reasonably
requested in order to further assure a Party of the rights and
benefits contemplated hereunder.
26. NOTICE OF SATISFACTION OF CONDITION SUBSEQUENT:
HSR and KMI shall notify Mr. Bruce Benson with UXP by
telephone at (303) 863-3551 on the day that the Condition
Subsequent is satisfied, to be followed immediately by a joint
written notice from HSR and KMI to the address shown below.
Within the first week of January, 2000, UXP shall be notified
by a joint written notice from HSR and KMI if the Condition
Subsequent was not satisfied by December 31, 1999. Failure of
the Condition Subsequent to be satisfied timely shall result
in this entire Agreement terminating ab initio, including the
Gathering Amendment, the Transportation Amendment, and the
Agency Amendment.
[The rest of this page left intentionally blank]
- 8 -
<PAGE> 9
IN WITNESS WHEREOF, the Parties hereto have executed this
document on the date first above written.
UNITED STATES EXPLORATION, INC.
By: /s/ Bruce D. Benson
---------------------------------
Bruce D. Benson, President
Address for Notice:
1560 Broadway, Suite 900
Denver, Colorado 80202
KINDER MORGAN, INC.
By: /s/ Jack W. Ellis II
---------------------------------
Name: Jack W. Ellis II
---------------------------
Title: VP & Controller
--------------------------
HS RESOURCES, INC.
By: /s/ Dale E. Cantwell
---------------------------------
Dale E. Cantwell, Vice President
RESOURCE GATHERING SYSTEMS, INC.
By: /s/ Dale E. Cantwell
---------------------------------
Dale E. Cantwell, Vice-President
- 9 -
<PAGE> 10
EXHIBITS OMITTED
- 10 -
<PAGE> 1
EXHIBIT 23.1
Consent of Independent Auditors
We consent to the incorporation by reference in the Registration Statement (Form
S-8 No. 333-60983) pertaining to the Amended and Restated 1989 Incentive Stock
Option Plan, Amended and Restated 1990 Nonqualified Stock Option Plan, Directors
Fee Stock Option Plan and Employment Agreement with Bruce D. Benson of United
States Exploration, Inc. of our report dated March 20, 2000, except for Notes 2
and 17 as to which the date is March 28, 2000, with respect to the 1999
consolidated financial statements of United States Exploration, Inc. included in
the Annual Report (Form 10-KSB) for the year ended December 31, 1999.
Denver, Colorado /s/ Ernst & Young LLP
April 13, 2000
<PAGE> 1
Exhibit 24
POWER OF ATTORNEY
I, the undersigned director of United States Exploration,
Inc., do hereby constitute and appoint Bruce D. Benson and F. Michael Murphy, or
either of them, to be my true and lawful attorneys-in-fact and agents, with full
power of substitution and resubstitution, and in my name, place and stead, in
any and all capacities, to sign to the Company's Annual Report on Form 10-KSB
for the year ended December 31, 1999 and any and all amendments thereto, and to
file the same, with all exhibits thereto, and other documents in connection
therewith, with the Securities and Exchange Commission, granting unto said
attorneys-in-fact and agents full power and authority to do and perform each and
every act and thing requisite and necessary to be done in connection therewith
and about the premises, as fully to all intents and purposes as I might or could
do in person, hereby ratifying and confirming all that said attorneys-in-fact
and agents, or any of them, or their or his substitute or substitutes, may
lawfully do or cause to be done by virtue thereof.
Dated this 11th day of April, 2000.
/s/ Richard L. Robinson
-----------------------------
Richard L. Robinson, Director
<PAGE> 2
POWER OF ATTORNEY
I, the undersigned director of United States Exploration,
Inc., do hereby constitute and appoint Bruce D. Benson and F. Michael Murphy, or
either of them, to be my true and lawful attorneys-in-fact and agents, with full
power of substitution and resubstitution, and in my name, place and stead, in
any and all capacities, to sign to the Company's Annual Report on Form 10-KSB
for the year ended December 31, 1999 and any and all amendments thereto, and to
file the same, with all exhibits thereto, and other documents in connection
therewith, with the Securities and Exchange Commission, granting unto said
attorneys-in-fact and agents full power and authority to do and perform each and
every act and thing requisite and necessary to be done in connection therewith
and about the premises, as fully to all intents and purposes as I might or could
do in person, hereby ratifying and confirming all that said attorneys-in-fact
and agents, or any of them, or their or his substitute or substitutes, may
lawfully do or cause to be done by virtue thereof.
Dated this 31st day of March, 2000.
/s/ T. W. Gamel
--------------------------
Thomas W. Gamel, Director
<PAGE> 3
POWER OF ATTORNEY
I, the undersigned director of United States Exploration,
Inc., do hereby constitute and appoint Bruce D. Benson and F. Michael Murphy, or
either of them, to be my true and lawful attorneys-in-fact and agents, with full
power of substitution and resubstitution, and in my name, place and stead, in
any and all capacities, to sign to the Company's Annual Report on Form 10-KSB
for the year ended December 31, 1999 and any and all amendments thereto, and to
file the same, with all exhibits thereto, and other documents in connection
therewith, with the Securities and Exchange Commission, granting unto said
attorneys-in-fact and agents full power and authority to do and perform each and
every act and thing requisite and necessary to be done in connection therewith
and about the premises, as fully to all intents and purposes as I might or could
do in person, hereby ratifying and confirming all that said attorneys-in-fact
and agents, or any of them, or their or his substitute or substitutes, may
lawfully do or cause to be done by virtue thereof.
Dated this 4th day of April, 2000.
/s/ Robert J. Malone
--------------------------
Robert J. Malone, Director
<PAGE> 4
POWER OF ATTORNEY
I, the undersigned officer and director of United States
Exploration, Inc., do hereby constitute and appoint F. Michael Murphy to be my
true and lawful attorney-in-fact and agent, with full power of substitution and
resubstitution, and in my name, place and stead, in any and all capacities, to
sign to the Company's Annual Report on Form 10-KSB for the year ended December
31, 1999 and any and all amendments thereto, and to file the same, with all
exhibits thereto, and other documents in connection therewith, with the
Securities and Exchange Commission, granting unto said attorney-in-fact and
agent full power and authority to do and perform each and every act and thing
requisite and necessary to be done in connection therewith and about the
premises, as fully to all intents and purposes as I might or could do in person,
hereby ratifying and confirming all that said attorney-in-fact and agent or his
substitute or substitutes, may lawfully do or cause to be done by virtue
thereof.
Dated this 3rd day of April, 2000.
/s/ Bruce D. Benson
-----------------------------------
Bruce D. Benson, President, Chief
Executive Officer, and Chairman of
the Board of Directors
<TABLE> <S> <C>
<ARTICLE> 5
<S> <C>
<PERIOD-TYPE> YEAR
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-START> JAN-01-1999
<PERIOD-END> DEC-31-1999
<CASH> 3,096,691
<SECURITIES> 0
<RECEIVABLES> 1,359,779
<ALLOWANCES> (10,000)
<INVENTORY> 2,792
<CURRENT-ASSETS> 4,513,979
<PP&E> 56,590,903
<DEPRECIATION> 30,607,968
<TOTAL-ASSETS> 31,562,870
<CURRENT-LIABILITIES> 35,699,431
<BONDS> 0
0
2,658,996
<COMMON> 1,559
<OTHER-SE> (6,797,116)
<TOTAL-LIABILITY-AND-EQUITY> 31,562,870
<SALES> 8,177,716
<TOTAL-REVENUES> 8,177,716
<CGS> 518,337
<TOTAL-COSTS> 9,634,957
<OTHER-EXPENSES> 0
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<INTEREST-EXPENSE> 2,666,314
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