<PAGE>
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
[X] Annual report pursuant to section 13 or 15(d) of the Securities Exchange
Act of 1934 for the fiscal year ended December 31, 1998
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 0-17162
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KEY PRODUCTION COMPANY, INC.
A Delaware Corporation IRS Employer No. 84-1089744
707 Seventeenth Street, Suite 3300
Denver, Colorado 80202
Telephone Number (303) 295-3995
SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:
Name of Each Exchange
Title of Each Class on Which Registered
----------------------------- -----------------------
Common Stock ($.25 par value) New York Stock Exchange
SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
NONE
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. YES X NO
----- -----
Aggregate market value of the voting stock held by non-affiliates of
Key Production Company, Inc. as of March 11, 1999 $77,664,459
Number of shares of Key Production Company, Inc. common stock outstanding
as of March 11, 1999 11,518,227
DOCUMENTS INCORPORATED BY REFERENCE:
Portions of the Registrant's Proxy Statement for its 1999 Annual Meeting of
Stockholders are incorporated by reference into Part III.
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not 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-K or any
amendment to this Form 10-K. X
-----
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TABLE OF CONTENTS
DESCRIPTION
<TABLE>
<CAPTION>
Item Page
- ---- ----
<S> <C>
PART I........................................................... 3
1. BUSINESS............................................. 3
2. PROPERTIES........................................... 6
3. LEGAL PROCEEDINGS.................................... 8
4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
EXECUTIVE OFFICERS OF THE REGISTRANT................. 8
PART II.......................................................... 10
5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTERS.................................. 10
6. SELECTED FINANCIAL DATA.............................. 10
7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS.................. 11
7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT
MARKET RISK.......................................... 15
8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.......... 17
9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
ACCOUNTING AND FINANCIAL DISCLOSURE.................. 36
PART III......................................................... 36
10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT*.. 36
11. EXECUTIVE COMPENSATION*.............................. 36
12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
AND MANAGEMENT*...................................... 36
13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS....... 37
PART IV... 37
14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS
ON FORM 8-K.......................................... 37
</TABLE>
* This information is incorporated herein by reference from
the Company's Proxy Statement for its 1999 Annual Meeting of
Stockholders.
All defined terms under Rule 4-10(a) of Regulation S-X shall have
their statutorily-prescribed meanings when used in this report. Quantities of
natural gas are expressed in this report in terms of thousand cubic feet (Mcf),
million cubic feet (MMcf) or billion cubic feet (Bcf). Oil is quantified in
terms of barrels (Bbls), thousands of barrels (MBbls) and millions of barrels
(MMBbls). Oil is compared to natural gas in terms of equivalent thousand cubic
feet (EMcf). One barrel of oil is the energy equivalent of six Mcf of natural
gas. With respect to information relating to the Company's working interest in
wells or acreage, "net" oil and gas wells or acreage is determined by
multiplying gross wells or acreage by the Company's working interest therein.
Unless otherwise specified, all references to wells and acres are gross.
Percentages are calculated on actual, unrounded numbers and may not agree with
percentages calculated off the rounded numbers presented in this Form 10-K.
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PART I
ITEM 1. BUSINESS
General
Key Production Company, Inc. (Key or the Company) is an independent oil and
gas company engaged in oil and gas exploration, development and production in
the continental United States. The Company's oil and gas interests are spread
over 14 states with primary focus areas in the Anadarko Basin of Oklahoma,
California, the Rocky Mountain region, North Texas, and the Gulf Coast. The
Company was incorporated in Delaware on June 22, 1988, and maintains its
corporate offices in Denver, Colorado. Key maintains regional exploration
offices in: Tulsa, Oklahoma; Sacramento, California; and New Orleans, Louisiana.
The Company's common stock trades on the New York Stock Exchange under the
symbol KP.
Business During 1998
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Key reported 1998 net income of $4.6 million, ($.38 per share) on revenues
of $37.8 million. Net cash provided by operating activities totaled $26.6
million. Oil and gas production was up 15 percent to 18.4 EBcf, a record high
production level for the Company. Product prices averaged $2.00 per Mcf for gas
and $11.78 per barrel for oil.
The Company produced 12,600 MMcf of gas and 965,000 barrels of oil during
1998. This was a 15 percent increase for both products compared to 1997
production levels. The increased gas production is attributable to production
from wells drilled since last year. Oil production increased both from new
drilling and as a result of production from properties acquired at the end of
the third quarter of 1997.
Key spent $42.2 million on exploration and development during 1998 and
drilled 82 gross (28.1 net) wells. Sixty-one wells were completed as producers
for an overall success rate of 74 percent. At year-end, 18 gross (5.0 net)
wells were in the process of being drilled.
Expenditures for acquisitions of proved and unproved properties totaled
$13.3 million. The primary transaction occurred on December 30, 1998, when Key
purchased EEX Corporation's (EEX) remaining producing and non-producing property
interests in the Hardeman Basin for $10.5 million. In September of 1997, Key
had entered into an exploration joint venture with EEX that entitled EEX to a 40
percent carried interest in 20 wells which Key was obligated to drill. At that
time, Key also purchased 20 percent of EEX's interest in producing properties in
the Hardeman Basin of north-central Texas and became the operator of those
properties. The 1998 purchase transaction terminated the exploration joint
venture agreement, relieving Key of its obligation to drill any additional wells
and terminated EEX's right to an interest in any wells drilled in the future.
Reserve additions from all sources (drilling, property acquisitions and
revisions of previous estimates) totaled 36.8 EBcf or 200 percent of current
year production. At year-end 1998, the Company had total proved reserves of
125.1 EBcf. Two-thirds of the Company's reserves are natural gas and more than
99 percent of the reserves are classified as proved developed. The SEC PV10
value of the reserves was $118.4 million at December 31, 1998.
Key owns working interests in approximately 1,968 gross (297.5 net) oil and
gas wells located primarily in Oklahoma, Wyoming, Texas, Louisiana, Mississippi
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and California. Key also owns royalty or overriding royalty interests in
approximately 1,997 oil and gas wells located primarily in these same states.
Key owns an interest in approximately 120,000 net acres of developed
leasehold located primarily in Oklahoma, Wyoming, Texas, Louisiana, Mississippi
and California. Key also owns an interest in approximately 207,300 net acres of
undeveloped leasehold located primarily in California, Mississippi, Oklahoma,
Texas, and Wyoming.
Competition
The oil and gas industry is highly competitive. As an independent oil and
gas company, Key must compete against companies with substantially larger
financial and other resources for a variety of opportunities including reserve
and lease acquisitions and marketing agreements.
Natural Gas and Oil Prices
The price Key received for its gas production averaged $2.00 per Mcf in
1998, $.38 lower than the prior year per Mcf average of $2.38. The price the
Company received per barrel of oil in 1998 was $11.78, down $6.26 from the
$18.04 per barrel received in the prior year. Historically, the Company has not
used financial instruments such as futures contracts or hedging agreements to
mitigate the impact of changes in commodity prices. Key's business will
continue to be affected by future changes in domestic and international oil and
gas prices. It is impossible to predict, with any substantial degree of
accuracy, the trend in, or level of, future oil and gas prices and their impact
on the Company's reported results in future periods.
Reserve Value Ceiling Test
Key reviews the carrying value of its oil and gas properties on a quarterly
basis under the full cost accounting rules of the Securities and Exchange
Commission (SEC or the Commission). Under the full cost accounting rules,
capitalized costs of oil and gas properties may not exceed the present value of
estimated future net revenues from proved reserves, discounted at 10 percent,
plus the lower of cost or fair market value of unproved properties, as adjusted
for related tax effects and deferred tax revenues. Application of this rule
generally requires pricing of future revenues at the unescalated prices in
effect at the end of each fiscal quarter and requires a write-down if the
"ceiling" is exceed, even if prices declined for only a short period of time.
If a write-down were required, the charge to earnings would not impact cash flow
from operating activities. Key has never taken such a write-down.
Regulation of Oil and Gas
Key's exploration, production and marketing activities are regulated
extensively at the federal, state and local levels. Oil and gas exploration,
development and production activities are subject to various laws and
regulations governing a wide variety of matters. For example, the states in
which Key produces oil and gas have statutes or regulations addressing
production practices that may affect Key's operations and limit the quantity of
hydrocarbons Key may produce and sell. Other regulated matters include the
marketing and transportation of oil and gas and the valuation of royalty
payments.
Among other regulated matters on the federal level, the Federal Energy
Regulatory Commission (FERC) regulates interstate transportation of natural gas
under the Natural Gas Act. Key's gas sales are affected by regulation of
intrastate and interstate gas transportation. In an attempt to promote
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competition, FERC has issued a series of orders that have significantly altered
the marketing and transportation of natural gas. To date, Key has not
experienced any material adverse effect on gas marketing as a result of these
FERC orders. However, the Company cannot predict what effect subsequent
regulations may have on its future gas marketing.
Environmental
Key, as an owner of interests in oil and gas properties, is subject to
various federal, state and local laws and regulations relating to discharge of
materials into, and protection of, the environment. These laws and regulations
may, among other things, impose liability on the lessee under an oil and gas
lease for the cost of pollution clean-up resulting from operations, subject the
lessee to liability for pollution damages, require restrictions on the injection
of liquids into subsurface aquifers that may contaminate groundwater.
Key has made and will continue to make expenditures in its efforts to
comply with the requirements, which it believes are necessary business costs in
the oil and gas industry. These costs are inextricably connected to normal
operating expenses such that the Company is unable to separate the expenses
related to environmental matters. However, the Company does not believe any
such additional expenses will materially affect its business. Although
environmental regulations do have a substantial impact upon the energy industry,
generally these requirements do not appear to affect Key any differently or to
any greater or lesser extent than any other companies in the industry.
The Company is not aware of any environmental claims existing as of
December 31, 1998, which would have a material impact upon the Company's
financial condition or results of operations. Key does not believe that
compliance with federal, state or local provisions regulating the discharge of
materials into the environment, or otherwise relating to the protection of the
environment, will have such an impact.
Employees
On December 31, 1998, Key had 61 full-time employees.
Offices
Key's principal executive offices are located at 707 Seventeenth Street,
Suite 3300, Denver, Colorado 80202-3404.
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ITEM 2. PROPERTIES
Productive Wells and Acreage
The number of productive gas and oil wells in which Key has working
interests as of December 31, 1998, is set forth below:
Gas Oil
--- ---
Gross Net Gross Net
----- ----- ----- -----
Mid-Continent* 618 114.6 185 58.5
Gulf Coast 166 21.1 183 25.4
Rocky Mountains 114 5.6 682 54.0
California 20 18.3 - -
--- ----- ----- -----
918 159.6 1,050 137.9
=== ===== ===== =====
* Includes wells previously reported as North Texas.
In addition, Key has royalty or overriding royalty interests in
approximately 94 properties in the Mid-Continent regions, 60 properties in the
Gulf Coast region, and 1,843 properties in the Rocky Mountain region. As of
December 31, 1998, Key held approximately 120,000 net developed acres.
Gross Wells Drilled
The following table sets forth the number of wells drilled during
1998, 1997, and 1996 in which the Company participated.
<TABLE>
<CAPTION>
Exploratory Developmental
----------- -------------
Productive Dry Total Productive Dry Total
---------- ----------- ----- ---------- ------------- -----
<S> <C> <C> <C> <C> <C> <C>
1998
----
Mid-Continent 1 6 7 30 4 34
Gulf Coast 2 1 3 6 1 7
Rocky Mountains 1 1 2 15 - 15
California 6 8 14 - - -
-- -- -- -- -- --
10 16 26 51 5 56
== == == == == ==
1997
----
Mid-Continent* 2 3 5 46 5 51
Gulf Coast - 1 1 9 1 10
Rocky Mountains - 1 1 14 - 14
California 7 6 13 - - -
-- -- -- -- -- --
9 11 20 69 6 75
== == == == == ==
* Includes wells previously reported as
North Texas.
1996
----
Mid-Continent 6 4 10 34 1 35
Gulf Coast 1 4 5 12 - 12
Rocky Mountains 2 2 4 8 - 8
California 6 1 7 - - -
-- -- -- -- -- --
15 11 26 54 1 55
== == == == == ==
</TABLE>
At December 31, 1998, 18 gross (5.0 net) wells were in the process of being
drilled.
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Undeveloped Acreage
As of December 31, 1998, Key held an interest in approximately 207,300 net
undeveloped acres. Approximately 45 percent of this acreage is located in the
Rocky Mountain region and approximately 30 percent is located in the Mid-
Continent region. The remaining acreage is divided among locations in
California, Mississippi, and Louisiana.
Production and Pricing Information
The following table describes, for each of the last three fiscal years, oil
and gas production and pricing data for the Company.
<TABLE>
<CAPTION>
Average
Production Average Sales Price
Oil Gas Cost -------------------
Year Ended December 31 MBbls MMcf Per EMcf Per Bbl Per Mcf
- ------------------------ ----- ------ ---------- --------- --------
<S> <C> <C> <C> <C> <C>
1998.................... 965 12,600 $.61 $11.78 $2.00
1997.................... 839 10,958 $.66 $18.04 $2.38
1996.................... 853 9,198 $.67 $20.30 $2.15
</TABLE>
Reserve Value Information
The estimated proved oil and gas reserves of Key, as of December 31, 1998,
1997 and 1996, and the standardized measure of discounted future net cash flows
attributable thereto at December 31, 1998, 1997 and 1996, are included in
Supplemental Oil and Gas Disclosures to Financial Statements appearing on pages
33 through 35 of this Form 10-K. Supplemental Oil and Gas Disclosures also
include Key's net revenues from production (including royalty and working
interest production) of oil and natural gas for the three years ended December
31, 1998.
Future reserve values are based on year-end prices except in those
instances where the sale of gas is covered by contract terms providing for
determinable escalations. Operating costs, production and ad valorem taxes and
future development costs are based on current costs with no escalations.
<TABLE>
<CAPTION>
Undiscounted Present Value of Estimated
Estimated Future Future Net Cash Flows Before
Net Cash Flows Income Tax
Before Income Tax (Discounted at 10 Percent)
------------------- ----------------------------
Proved Proved
Year Ended December 31, Proved Developed Proved Developed
- ------------------------- -------- --------- ------------- -------------
(In thousands)
<S> <C> <C> <C> <C>
1998..................... $170,117 $169,074 $118,419 $117,870
1997..................... $175,001 $171,861 $121,718 $119,620
1996..................... $265,541 $257,704 $172,583 $167,983
</TABLE>
The present value of estimated future net cash flows from proved
reserves after income taxes are $104,222,000, $99,253,000, $129,220,000 for
1998, 1997 and 1996, respectively.
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Estimated undiscounted, before tax future net cash flows at December
31, 1998, are expected to be received as shown in the following years:
<TABLE>
<CAPTION>
Proved
Year Ended December 31, Proved Developed
- ------------------------- -------- ---------
(In thousands)
<S> <C> <C>
1999..................... $ 34,941 $ 34,941
2000..................... 28,108 28,261
2001..................... 21,350 21,137
Thereafter............... 85,718 84,735
-------- --------
Total.................... $170,117 $169,074
======== ========
</TABLE>
No major discovery or other favorable or adverse event is believed to
have occurred since December 31, 1998, which would cause significant change in
the estimated proved reserves reported herein. The above estimates are based on
year-end pricing in accordance with Commission guidelines and do not reflect
current prices. Since January 1, 1999, no oil or gas reserve information has
been filed with, or included in any report to, any federal authority or agency
other than the SEC and/or the Energy Information Administration.
ITEM 3. LEGAL PROCEEDINGS
The Company is not subject to any pending litigation that, in the opinion
of the Company's management, will materially affect the financial position or
results of operations of the Company.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted for a vote of security holders during the
fourth quarter of 1998.
EXECUTIVE OFFICERS OF THE REGISTRANT
F.H. MERELLI, 62, has been chairman of the board of directors, president
and chief executive officer of the Company since September 9, 1992. From July
1991 to September 1992, Mr. Merelli was engaged as a private consultant in the
oil and gas industry. Mr. Merelli was president and chief operating officer of
Apache Corporation, and president, chief operating officer and a director of Key
from June 1988 to July 1991, at which time he resigned from those positions in
both companies. He was president of Terra Resources, Inc. from 1979 to 1988.
Mr. Merelli has been a director of Apache Corporation since July 1997.
MONROE W. ROBERTSON, 48, has been with the Company since September 10,
1992. Since February 1994, he has served as senior vice president and corporate
secretary and prior to that time as vice president and corporate secretary.
From August 1988 to July 1992, he was employed by Apache Corporation in various
capacities, the most recent of which was as director of operational planning.
From 1986 to 1988, Mr. Robertson was director of corporate planning for Terra
Resources, Inc. From 1973 to 1986, Mr. Robertson was employed by Gulf Oil
Corporation in various engineering and management positions.
CATHY L. ANDERSON, 43, has been controller of the Company since January 15,
1993. From July 1985 to January 1993, Ms. Anderson was employed by Arthur
Andersen LLP, a public accounting firm, in various capacities, the most recent
of which was audit manager.
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STEPHEN P. BELL, 44, has been vice president - land of the Company since
February 2, 1994. From March 1991 to February 1994, he was president of Concord
Reserve, Inc., a privately-held independent oil and gas company. He was
employed by Pacific Enterprises Oil Company (formerly Terra Resources, Inc.) as
Mid-Continent regional manager from February 1990 to February 1991 and as land
manager from August 1985 to January 1990.
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PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
Key's common stock, par value $.25 per share, trades on the New York
Stock Exchange under the symbol KP. No dividends were paid in 1998 or in 1997.
The table below shows the market price of the common stock for 1998 and 1997:
<TABLE>
<CAPTION>
MARKET PRICE
----------------------------------
1998 1997
---------------- ----------------
High Low High Low
------- ------- ------- -------
<S> <C> <C> <C> <C>
First Quarter $11.625 $ 9.937 $13.250 $9.625
Second Quarter $12.625 $10.000 $10.750 $8.000
Third Quarter $12.250 $ 5.875 $13.250 $9.625
Fourth Quarter $ 9.500 $ 5.000 $13.188 $9.000
</TABLE>
The closing price of Key's common stock as reported on the New York Stock
Exchange for March 11, 1999, was $6.937. At December 31, 1998, the Company's
11,518,456 shares of common stock outstanding were held by approximately 5,900
stockholders of record and approximately 7,200 beneficial owners.
ITEM 6. SELECTED FINANCIAL DATA
The following table sets forth selected financial data of the Company for
each of the years in the five-year period ended December 31, 1998, which
information has been derived from the Company's audited financial statements.
This information should be read in connection with and is qualified in its
entirety by the more detailed information and financial statements under Item 8
below.
<TABLE>
<CAPTION>
For the Year Ended December 31,
---------------------------------------------
1998 1997 1996 1995 1994
-------- -------- ------- ------- -------
(In thousands, except per share data)
<S> <C> <C> <C> <C> <C>
Revenues...................... $ 37,783 $ 42,151 $37,886 $19,297 $16,637
Net income.................... 4,595 9,696 7,980 3,054 2,943
Basic earnings per share.... .40 .84 .73 .34 .30
Diluted earnings per share.. .38 .80 .69 .32 .29
Oil and gas expenditures...... 55,429 44,625 43,476 13,591 29,966
Total assets.................. 166,295 130,647 95,940 59,199 52,611
Long-term debt................ 60,000 35,000 22,500 14,600 10,000
Stockholders' equity.......... 69,681 64,911 55,269 35,699 34,257
</TABLE>
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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
Financial Results
Key reported 1998 net income of $4.6 million, a decrease of 53 percent
or $5.1 million from 1997. The decrease is primarily due to a decline in
commodity prices. Basic net income per share dropped to $.40 per common share
compared to $.84 per common share in 1997; diluted net income per common share
slipped to $.38 in 1998 from $.80 in 1997. Net income of $9.7 million for 1997
rose $1.7 million over the $8.0 million reported in 1996. On a per share basis,
basic net income increased to $.84 in 1997 from $.73 in 1996, while diluted
earnings per share climbed to $.80 in 1997 from $.69 in 1996. Gains in 1997 can
be attributed to significant production increases from new drilling. Earnings
for 1998, 1997 and 1996 are based on revenues of $37.8, $42.2 and $37.9 million,
respectively.
Revenues
Oil and gas production revenues decreased 11 percent to $37.4 million
between 1998 and 1997 despite record production in 1998. A healthy increase to
production from new drilling wells was not enough to mitigate the effect of
falling product prices.
Oil and gas production revenues increased 12 percent between 1997 and 1996
as a result of increases in gas production and gas prices. Oil production and
oil prices decreased in 1997, but were more than offset by increases in gas
sales. Key's oil and gas revenues were $42.0 million in 1997 compared to $37.6
million in 1996.
Key's gas sales for 1998 of $25.2 million reflect a 3 percent decrease from
1997. Daily production expanded from 30,021 Mcf per day in 1997 to 34,520 Mcf
per day in 1998, a 15 percent increase. The increase in production added $3.9
million to gas sales. The average daily price slipped from $2.38 per Mcf in
1997 to $2.00 per Mcf in 1998 and had a negative $4.9 million impact.
Gas sales were $26.1 million in 1997, reflecting a 32 percent increase over
1996 gas sales. Daily production increased from 25,132 Mcf per day in 1996 to
30,021 Mcf per day in 1997. Production increases contributed approximately $3.8
million to gas sales. Roughly 80 percent of the 1997 gas production increase is
from new drilling. The balance of the increase can be attributed to the Brock
acquisition at the end of March 1996. Key's average realized price increased
from $2.15 per Mcf in 1996 to $2.38 per Mcf in 1997, for an additional $2.5
million in gas sales.
Oil sales for 1998 fell 25 percent to $11.4 million. Most of the decline,
$6.0 million, is due to low crude oil prices. Key's average price realization
for this period went from $18.04 per barrel in 1997 to $11.78 per barrel in
1998. On the upside, daily production climbed from 2,298 barrels per day in
1997 to 2,643 barrels per day in 1998. The 15 percent production gain added
$2.3 million in value, but was not enough to overcome the steep decline in oil
prices.
Oil sales went from $17.3 in 1996 to $15.1 million in 1997. Key's average
realized oil price dropped from $20.30 per barrel in 1996 to $18.04 per barrel
in 1997. Price declines are responsible for approximately $1.9 million of the
$2.2 million oil sales variance. Oil production slipped from 2,332 barrels per
day in 1996 to 2,298 barrels per day in 1997. The overall decrease to oil
production occurred even with the acquisition of producing oil properties in the
third quarter of 1997. The production decline was only 2 percent, but had a
negative
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$.3 million impact on sales. The third quarter acquisition added almost $.5
million to oil sales.
Product sales from gas processing plants contributed approximately
$828,000, $748,000 and $459,000 to oil and gas production revenues in 1998, 1997
and 1996, respectively.
Key's oil and gas revenues are derived from the following product mix in
1998: 30 percent oil, 67 percent gas and 3 percent plant products. This
compares to the following mix for 1997: 36 percent oil, 62 percent gas and 2
percent plant products.
Other revenues were approximately $370,000, $186,000 and $333,000 for 1998,
1997 and 1996, respectively. Other revenues in 1998 include income from the
Company's new gathering system in California. Key's primary source of other
revenue in 1997 was income from a pipeline acquired in the 1996 Brock
acquisition. This pipeline was subsequently sold in March of 1997, resulting in
a decrease to other revenues between 1997 and 1996. Other revenue for 1996 also
includes a contract settlement for $123,000. The remaining other revenues for
all periods presented includes proceeds from gas contract settlements and
miscellaneous income items.
Costs and Expenses
Depreciation, depletion and amortization (DD&A) expense increased 23
percent between 1997 and 1998 while sales decreased by 11 percent. The
depletion rate as a percentage of oil and gas sales escalated from 30.9 percent
in 1997 to 42.3 percent in 1998. Depressed product prices, for both oil and
gas, were a factor in the elevated DD&A rate for 1998.
DD&A expense increased just 4 percent between 1997 and 1996, while oil and
gas revenues increased by 12 percent. A decrease in the depletion rate from
33.3 percent in 1996 to 30.9 percent in 1997 mitigated the effect of higher oil
and gas sales in 1997. Improved gas prices and new reserves from drilling each
contributed to the favorable DD&A in 1997. Included in DD&A expense for the
three years presented is a small amount of depreciation on fixed assets and
amortization of financing costs associated with the Company's credit facility.
The increase in production increased operating costs 6 percent between 1997
and 1998, as expected. Total operating costs were $11.3 million and $10.6
million for 1998 and 1997, respectively. Compared on a unit of production
basis, expenses decreased 8 percent, or $.05 per EMcf to $.61 per EMcf in 1998.
Operating expenses for 1997 moved upward in direct correlation with oil and
gas sales. On a unit of production basis, operating expenses declined from $.67
per EMcf in 1996 to $.66 per EMcf in 1997. Operating expenses for 1997 include
a $.2 million credit Key received for charges over-billed by an operator.
Without this credit, 1997 and 1996 expenses on a unit of production basis would
have remained flat at $.67 per EMcf.
Administrative, selling and other costs (G&A) went from $2.0 million in
1997 to $1.7 million in 1998, a 17 percent decrease. With a 15 percent increase
in oil and gas production, this translates to $.09 and $.13 per EMcf in 1998 and
1997, respectively. Due to certain economies of scale and full cost accounting
rules, which provide for the capitalization of direct overhead related to
acquisition, exploration and development activities, the Company was able to
maintain or reduce administrative expense while managing an active drilling
program and a larger asset base.
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For 1997 and 1996, G&A held steady at $2.0 million and $2.1 million,
respectively. Complemented by an increase in oil and gas output, this small
overall decrease equates to a 10 percent, or $.01 per EMcf decrease between 1996
and 1997.
Interest expense before capitalization was $2,752,000, $1,718,000 and
$1,349,000 for 1998, 1997 and 1996, respectively. The long-term debt balance
was $60.0 million at December 31, 1998, compared to $35.0 million at December
31, 1997. Key capitalized interest of $1,456,000, $1,019,000 and $682,000 in
1998, 1997 and 1996, respectively. These capitalized amounts are for borrowings
associated with undeveloped leasehold.
As discussed in more detail in Footnote 3, "Income Taxes", in connection
with the acquisition of Brock, a deferred income tax valuation was established
for NOLs that are subject to annual limitations and expected expirations. Key
is using an effective tax rate of 38 percent for 1998, 1997 and 1996.
Cash Flow and Liquidity
Key's primary needs for cash are to fund oil and gas exploration,
development and acquisition activities and for payment of existing obligations
and trade commitments related to oil and gas operations. The Company's primary
sources of liquidity are cash flows from operating activities and proceeds from
financing activities.
Cash from operating activities was $26.6 million in 1998, compared to $34.1
million in 1997. The $7.5 million, or 22 percent, decrease can be traced back
to the depressed commodity prices and the resulting lower sales. Changes to net
income, DD&A expense and deferred taxes in 1998 account for $5.6 million of the
decrease. The rest of the decrease is from the net changes in the accounts
receivable and accrued expense balances.
Between 1996 and 1997, cash from operating activities climbed from $21.9
million to $34.1 million, a 56 percent increase. Of this increase, $3.4 million
is due to increases in net income, DD&A expense and deferred taxes. Other
factors contributing to the variance were changes in the accounts payable and
accounts receivable balances.
Expenditures for exploration and development for 1998 totaled $39.8
million, or 150 percent of cash from operating activities. This is a 10 percent
increase over the $36.3 million spent in 1997 and almost twice as much as the
$20.0 million spent in 1996. In 1998, exploration and development projects were
funded with a combination of cash from operations and long-term debt. Key
drilled 82 gross wells (28.1 net) in 1998, 95 gross wells (25.8 net) in 1997 and
81 gross wells (17.6 net) in 1996.
On March 28, 1996, Key consummated a merger with Brock Exploration
Corporation. In this non-cash transaction, Brock became a wholly-owned
subsidiary of Key. Key's consolidated balance sheet includes the assets and
liabilities, as well as the adjustments required to record the acquisition under
purchase accounting rules.
In the second quarter of 1997, Key acquired non-producing acreage over
several salt domes in west-central Mississippi. In the third quarter of 1997,
Key acquired producing properties in the Hardeman Basin of north-central Texas.
Both transactions were funded with a combination of cash from operating
activities and funds obtained from the Company's credit facility.
-13-
<PAGE>
In 1998, Key purchased the remaining interest in oil and gas properties in
the Hardeman Basin of north-central Texas for $10.5 million. Key already held
an interest in these properties and was operator of the wells since the third
quarter of 1997. Key acquired other properties in 1998 for a total of $2.7
million.
Key has received various proceeds totaling $3.4 million in 1998 for the
sale of miscellaneous producing properties and non-producing acreage.
Key has a $75 million credit facility with NationsBank of Texas, N.A. In
1998, the Company executed an amendment to the Agreement that increased the
maximum loan amount from $50 million to $75 million and changed the borrowing
base from $42 million in 1997 to $70 million at the end of 1998. The Company
borrowed an additional $25.0 million in 1998 and a net $12.5 million in 1997 to
fund various acquisition, exploration and development projects. In 1996, Key
drew on its own credit facility to retire debt assumed in the Brock acquisition
and to obtain more favorable financing terms.
Semi-annually, the Bank determines the maximum allowable borrowing base.
The amount of the borrowing base is determined, at the Bank's discretion, by the
value it assigns to the oil and gas properties of the Company less any
outstanding debt. The Bank may also consider other credit factors such as
assets, liabilities, cash flow, properties, prospects, management and ownership.
If the re-determined borrowing base falls below the balance of outstanding
borrowings, the Bank may request repayment of the excess amount.
In the second quarter of 1997, Key purchased 40,000 shares of Key common
stock from Janet Moylan for $.4 million, or $10.00 per share. In the fourth
quarter of 1996, Key purchased 224,022 shares of Key common stock from Lawrence
Brock for $2.2 million, or $10.00 per share.
Management believes that cash on hand at year-end, net cash generated from
operations and remaining amounts available under the existing line of credit
will be adequate to meet future liquidity needs, including satisfying the
Company's financial obligations and funding operations, exploration and
development activities.
Year 2000 Compliance
Many existing computer programs use only two digits to identify a year in
the date field and were developed without considering the impact of the upcoming
change in the century. If not corrected, date-sensitive software applications
could fail or create erroneous results by or at the Year 2000.
During 1997, Key conducted an assessment of the various computer hardware
and software systems it uses. This assessment identified date-sensitive
software systems used to record, process and track information in three
functional areas: accounting, land and lease records and reservoir engineering.
The land and lease records and reservoir engineering software was found to be
Year 2000 compliant. During 1998, the accounting system was upgraded to make it
Year 2000 compliant. Testing of all three systems was conducted throughout the
year, and the Company believes that these systems will continue to function
properly when the century changes. The cost of the accounting system upgrade
was provided, at no additional charge, as part of the Company's annual software
maintenance agreement with the vendor. The cost of installing the software and
testing the systems was not material and was charged to expense during 1998.
The Company feels that its remediation plan has adequately addressed the
Year 2000 problem, and therefore, this issue is not expected to have a material
effect on the Company's internal operations. The Company has also attempted to
-14-
<PAGE>
assess the impact of this issue on the various entities with which the Company
does business. Although failure of these entities to adequately address the
Year 2000 issue could indirectly impact the Company, it is not possible to
quantify that impact, if any. However, the Company does not anticipate that the
impact would have a material adverse effect on the Company's business.
Future Trends
Key expects drilling to continue to be the primary focus of its growth
strategy in 1999 and beyond. Exploration and development activity will be
concentrated in three areas: the Mid-Continent, the on-shore Gulf Coast and
California. The Rocky Mountain region is significant to Key in terms of
production and reserves, but is not a primary exploration area at this time due
to the risk profile of the prospects we have generated.
Key expects to drill a significant number of wells in these areas during
the upcoming year. However, diminished cash flow as a result of depressed
commodity prices will impact the availability of drilling capital and,
ultimately, the number of wells the Company is able to drill during 1999. The
level of oil and gas prices also affects the borrowing base under the Company's
line of credit. Continued low prices could limit the Company's ability to
borrow additional amounts to fund exploration and development activities.
At year-end 1998, most of Key's employees previously located in Dallas were
transferred to the Mid-Continent region office in Tulsa. Exploration and
development activities for the Hardeman Basin of north-central Texas are now
carried out from the Tulsa office. Key maintains a small office in Dallas to
handle Hardeman Basin land work.
As part of its on-going business strategy, Key will continue to evaluate
merger and acquisition opportunities. Acquisition or merger candidates with the
economic and strategic attributes necessary to facilitate the profitable growth
of the Company will be actively pursued.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
The Company is exposed to market risk as a result of changes in the price
of natural gas and crude oil and changes in interest rates.
Natural gas and crude oil prices fluctuate widely in response to changing
market forces. Virtually 100 percent of the Company's revenue derives from the
sale of natural gas and crude oil, so these fluctuations, positive and negative,
can have a significant impact on the revenue the Company reports each period.
Changes in product prices also impact the calculation of the limitation on
capitalized costs under the full cost accounting rules of the Securities and
Exchange Commission. Application of this rule generally requires pricing future
revenues at the unescalated prices in effect at the end of each fiscal quarter
and requires a write-down if the "ceiling" is exceeded, even if prices decline
for only a short period of time. If a write-down were required, the charge to
earnings would not impact cash flow from operating activities. Key has never
taken a full-cost ceiling write-down.
The Company's reported earnings are impacted by changes in interest rates
as a result of its long-term debt with floating interest rates. Interest
charges are based on either the prime rate or the LIBOR rate. Fluctuations in
these rates directly impact the amount of interest expense the Company reports
in each period.
-15-
<PAGE>
Historically, the Company has not used financial instruments such as
futures contracts or interest rate swaps to mitigate the impact of changes in
commodity prices or interest rates.
CAUTIONARY STATEMENT PURSUANT TO SAFE HARBOR PROVISION OF THE PRIVATE SECURITIES
LITIGATION REFORM ACT OF 1995
This report contains "forward-looking statements" within the meaning of the
federal securities law. These forward-looking statements include, among others,
statements concerning the Company's outlook with regard to production levels,
price realizations, expenditures for exploration and development, plans for
funding operations and capital expenditures, and other statements of
expectations, beliefs, future plans and strategies, anticipated events or trends
and similar expressions concerning matters that are not historical facts. The
forward-looking statements in this report are subject to risks and uncertainties
that could cause actual results to differ materially from those expressed in or
implied by the statements.
These risks and uncertainties include, but are not limited to, fluctuations
in the price the Company receives for its oil and gas production, reductions in
the quantity of oil and gas sold due to decreased industry-wide demand and/or
curtailments in production from specific properties due to mechanical, marketing
or other problems, operating and capital expenditures that are either
significantly higher or lower than anticipated because the actual cost of
identified projects varied from original estimates and/or from the number of
exploration and development opportunities being greater or fewer than currently
anticipated, and increased financing costs due to a significant increase in
interest rates. These and other risks and uncertainties affecting the Company
are discussed in greater detail in this report and in other filings by the
Company with the Securities and Exchange Commission.
-16-
<PAGE>
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
See following Index.
KEY PRODUCTION COMPANY, INC.
INDEX TO FINANCIAL STATEMENTS AND SUPPLEMENTAL SCHEDULES
<TABLE>
<CAPTION>
Page
----
<S> <C>
Report of independent public accountants.............................. 18
Consolidated statement of income for each of the three years in the
period ended December 31, 1998...................................... 19
Consolidated statement of cash flows for each of the three years in
the period ended December 31, 1998.................................. 20
Consolidated balance sheet as of December 31, 1998 and 1997........... 21
Consolidated statement of stockholders' equity for each of the three
years in the period ended December 31, 1998......................... 22
Summary of significant accounting policies............................ 23
Notes to consolidated financial statements............................ 26
Supplemental oil and gas disclosures.................................. 33
Supplemental quarterly financial data................................. 36
</TABLE>
All other supplemental information and schedules have been omitted because
they are not applicable or the information required is shown in the consolidated
financial statements or related notes thereto.
-17-
<PAGE>
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Stockholders of Key Production Company, Inc.:
We have audited the accompanying consolidated balance sheets of Key
Production Company, Inc. (a Delaware corporation) and subsidiaries as of
December 31, 1998 and 1997, and the related consolidated statements of income,
stockholders' equity and cash flows for each of the three years in the period
ended December 31, 1998. 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 generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurances 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 consolidated financial statements referred to above
present fairly, in all material respects, the financial position of Key
Production Company, Inc. and subsidiaries as of December 31, 1998 and 1997, and
the results of its operations and its cash flows for each of the three years in
the period ended December 31, 1998, in conformity with generally accepted
accounting principles.
ARTHUR ANDERSEN LLP
Denver, Colorado,
February 24, 1999.
-18-
<PAGE>
KEY PRODUCTION COMPANY, INC.
CONSOLIDATED STATEMENT OF INCOME
<TABLE>
<CAPTION>
For the Year Ended December 31,
----------------------------------------
1998 1997 1996
------------ ------------ ------------
(In thousands, except per share data)
<S> <C> <C> <C>
Revenues:
Natural gas production.................... $25,217 $26,084 $19,772
Oil production............................ 11,368 15,133 17,322
Plant production.......................... 828 748 459
Other..................................... 370 186 333
------- ------- -------
37,783 42,151 37,886
------- ------- -------
Operating Expenses:
Depreciation, depletion and amortization.. 16,255 13,245 12,688
Operating costs........................... 11,283 10,627 9,639
Administrative, selling and other......... 1,697 2,045 2,069
Financing costs:
Interest expense......................... 1,296 699 667
Interest income.......................... (160) (104) (48)
------- ------- -------
30,371 26,512 25,015
------- ------- -------
Income Before Income Taxes................. 7,412 15,639 12,871
Provision for Income Taxes................. 2,817 5,943 4,891
------- ------- -------
Net Income.................................. $ 4,595 $ 9,696 $ 7,980
======= ======= =======
Basic earnings per share.................... $.40 $.84 $.73
======= ======= =======
Diluted earnings per share.................. $.38 $.80 $.69
======= ======= =======
</TABLE>
The accompanying Summary of Significant Accounting Policies
and Notes to Consolidated Financial Statements
are an integral part of this statement.
-19-
<PAGE>
KEY PRODUCTION COMPANY, INC.
CONSOLIDATED STATEMENT OF CASH FLOWS
<TABLE>
<CAPTION>
For the Year Ended December 31,
----------------------------------
1998 1997 1996
---------- ---------- ----------
(In thousands)
<S> <C> <C> <C>
Cash Flows from Operating Activities:
Net income.............................. $ 4,595 $ 9,696 $ 7,980
Adjustments to reconcile net income to
net cash provided by operating
activities:
Depreciation, depletion and
amortization....................... 16,255 13,245 12,688
Deferred income taxes................ 2,420 5,943 4,854
Changes in operating assets and
liabilities, net of the effect of
businesses acquired:
(Increase) decrease in receivables... 2,276 (1,631) (4,173)
(Increase) decrease in prepaid
expenses and other................. (189) 494 (114)
Increase in accounts payable and
accrued expenses................... 1,676 7,023 582
Increase (decrease) in long-term
property liabilities and other..... (406) (664) 81
-------- -------- --------
Net cash provided by operating
activities......................... 26,627 34,106 21,898
-------- -------- --------
Cash Flows from Investing Activities:
Oil and gas exploration and
development expenditures............... (39,810) (36,286) (20,021)
Acquisition of oil and gas properties... (13,253) (7,906) (1,633)
Cash received in connection with
acquisition, net of purchase
adjustments............................ - - 2,098
Proceeds from sale of oil and gas
properties............................. 3,411 726 878
Other capital expenditures.............. (601) (1,027) (171)
-------- -------- --------
Net cash used by investing
activities (50,253) (44,493) (18,849)
-------- -------- --------
Cash Flows From Financing Activities:
Long-term borrowings.................... 25,000 17,000 14,704
Payments on long-term debt.............. - (4,500) (14,754)
Payments to acquire treasury stock...... (3) (414) (2,246)
Proceeds from issuance of common stock.. - 69 237
-------- -------- --------
Net cash provided (used) by
financing activities............... 24,997 12,155 (2,059)
-------- -------- --------
Net Increase in Cash
and Cash Equivalents.................... 1,371 1,768 990
Cash and Cash Equivalents at Beginning
of Year................................. 3,349 1,581 591
-------- -------- --------
Cash and Cash Equivalents at End of Year.. $ 4,720 $ 3,349 $ 1,581
======== ======== ========
</TABLE>
The accompanying Summary of Significant Accounting Policies and Notes
to Consolidated Financial Statements are an
integral part of this statement.
-20-
<PAGE>
KEY PRODUCTION COMPANY, INC.
CONSOLIDATED BALANCE SHEET
<TABLE>
<CAPTION>
December 31,
--------------------
ASSETS 1998 1997
--------- ---------
(In thousands, except share data)
<S> <C> <C>
Current Assets:
Cash and cash equivalents............................. $ 4,720 $ 3,349
Receivables........................................... 7,978 10,254
Prepaid expenses and other............................ 569 380
-------- --------
13,267 13,983
-------- --------
Oil and Gas Properties, on the basis of
full cost accounting:
Proved properties..................................... 185,813 138,447
Unproved properties and properties
under development, not being amortized............... 23,276 18,624
-------- --------
209,089 157,071
Less - accumulated depreciation,
depletion and amortization........................... (57,752) (41,919)
-------- --------
151,337 115,152
-------- --------
Other Assets, net....................................... 1,691 1,512
-------- --------
$166,295 $130,647
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable...................................... $ 11,271 $ 11,290
Accrued exploration and development................... 3,651 1,285
Accrued lease operating expense and other............. 2,276 729
-------- --------
17,198 13,304
-------- --------
Long-Term Debt.......................................... 60,000 35,000
-------- --------
Non-Current Liabilities
Deferred income taxes................................. 18,123 15,703
Long-term property liabilities and other.............. 1,293 1,729
-------- --------
19,416 17,432
-------- --------
Commitments and Contingencies (Notes 6 and 7)
Stockholders' Equity:
Common stock, $.25 par value, 50,000,000 shares
authorized, 11,778,190 and 11,776,190 shares
issued, respectively................................. 2,945 2,944
Paid-in capital....................................... 37,406 37,380
Retained earnings..................................... 31,737 27,165
Treasury stock at cost, 259,734 and 277,835
shares, respectively................................. (2,407) (2,578)
-------- --------
69,681 64,911
-------- --------
$166,295 $130,647
======== ========
</TABLE>
The accompanying Summary of Significant Accounting Policies
and Notes to Consolidated Financial Statements
are an integral part of this statement.
-21-
<PAGE>
KEY PRODUCTION COMPANY, INC.
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
<TABLE>
<CAPTION>
Total
Common Paid-in Retained Treasury Stockholders'
Stock Capital Earnings Stock Equity
------ ------- -------- -------- -------------
(In thousands)
<S> <C> <C> <C> <C> <C>
Balance, December 31, 1995 $2,914 $34,401 $ 9,489 $(11,105) $35,699
Net income................ - - 7,980 - 7,980
Common stock issued....... 14 (120) - - (106)
Treasury stock issued..... - 2,964 - 10,978 13,942
Treasury stock purchased.. - - - (2,246) (2,246)
------ ------- ------- -------- -------
Balance, December 31, 1996 2,928 37,245 17,469 (2,373) 55,269
Net income................ - - 9,696 - 9,696
Common stock issued....... 16 111 - - 127
Treasury stock issued..... - 24 - 209 233
Treasury stock purchased.. - - - (414) (414)
------ ------- ------- -------- -------
Balance, December 31, 1997 2,944 37,380 27,165 (2,578) 64,911
Net income................ - - 4,595 - 4,595
Common stock issued....... 1 7 - - 8
Treasury stock issued..... - 19 (23) 174 170
Treasury stock purchased.. - - - (3) (3)
------ ------- ------- -------- -------
Balance, December 31, 1998 $2,945 $37,406 $31,737 $ (2,407) $69,681
====== ======= ======= ======== =======
</TABLE>
The accompanying Summary of Significant Accounting Policies
and Notes to Consolidated Financial Statements
are an integral part of this statement.
-22-
<PAGE>
KEY PRODUCTION COMPANY, INC.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Business
Key Production Company, Inc. (Key or the Company) was formed in 1988.
Key is an independent oil and gas company engaged in oil and gas exploration,
development and production in the continental United States. The Company's
exploration interests are spread over 14 states with primary focus areas in the
Anadarko Basin of Oklahoma, California, the Rocky Mountain region, north-central
Texas and the Gulf Coast.
Basis of Presentation
Key consummated the acquisition of Brock Exploration Corporation and
its wholly-owned subsidiaries, Brock Oil and Gas Corporation and Brock Gas
Systems & Equipment, Inc. (Brock) on March 28, 1996 in a tax-free reorganization
pursuant to which Brock became a wholly-owned subsidiary of Key. To effect the
transaction, each Brock shareholder received one share of Key common stock for
each 1.45 Brock shares held. The accompanying consolidated financial statements
include accounts of Key for 1998, 1997, and 1996 and the accounts of Brock for
the periods subsequent to the acquisition.
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the
reporting period. Actual results could differ from those estimates.
Oil and Gas Properties
The Company follows the full cost method of accounting for its
investment in oil and gas properties and, accordingly, capitalizes all
exploration and development costs incurred for the purposes of finding oil and
gas reserves, including dry hole costs, geological and geophysical costs and
direct overhead related to exploration and development activities. Payroll and
other internal costs capitalized included salaries and related benefits paid to
employees directly engaged in the acquisition, exploration and development of
oil and gas properties, as well as other specifically identifiable internal
costs. Future development, site restoration, dismantlement and abandonment
costs, net of salvage values, are estimated on a property-by-property basis
using prevailing prices. No gains or losses are normally recognized on the sale
or disposition of oil and gas properties under full cost accounting.
Key computes the provision for depreciation, depletion and
amortization (DD&A) of oil and gas properties on a quarterly basis using the
future gross revenue method. The quarterly provision is calculated by
multiplying the quarter's oil and gas revenues by an overall rate determined by
dividing the total unamortized cost of oil and gas properties including
estimated future development costs (excluding the cost of investments in
unproved and unevaluated properties) by the total estimated future oil and gas
revenues.
-23-
<PAGE>
KEY PRODUCTION COMPANY, INC.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
In accordance with rules prescribed by the Securities and Exchange
Commission, capitalized costs of oil and gas properties, net of accumulated
DD&A, are limited to the estimated future net cash flows from proved oil and gas
reserves discounted at 10 percent, plus the lower of cost or fair market value
of unproved properties as adjusted for related tax effects (the "full cost
ceiling test limitation"). This limit may be particularly sensitive to changes
in the near term in pricing and production rates. If capitalized costs exceed
this limit, the excess is charged to DD&A expense. The Company has not recorded
any such write-downs of capitalized costs.
The costs of certain unevaluated leasehold acreage and wells in the
process of being drilled are not amortized. Amortization commences when such
costs are evaluated or upon completion of wells in progress. Costs not being
amortized are periodically assessed for possible impairments or reductions in
value. If a reduction in value has occurred, the portion of the carrying cost
in excess of the current value is included in the costs subject to amortization.
Interest costs related to undeveloped properties are also capitalized.
Financing costs were reduced by capitalized interest totaling $1,456,000,
$1,019,000 and $682,000 in 1998, 1997, and 1996, respectively.
Office furniture and equipment are recorded at cost and depreciated on
a straight-line basis over the estimated useful lives of the assets, which range
from five to 10 years.
Revenue Recognition
Key uses the sales method of accounting for natural gas revenues.
Under this method, revenues are recognized based on actual volumes of gas sold
to purchasers. The volumes of gas sold may differ from the volumes to which Key
is entitled based on its interests in the properties. Differences between
volumes sold and entitlement volumes create gas imbalances. These imbalances
are reflected as adjustments to reported gas reserves and future cash flows in
the Company's reserve report. Adjustments for gas imbalances reduced Key's
proved gas reserves by approximately 3 percent at December 31, 1998. Key
recognizes revenues from oil based on actual volumes sold to purchasers.
Income Taxes
The Company utilizes an asset and liability approach to account for
income taxes. A deferred tax liability or asset is determined based upon the
temporary differences between the financial reporting basis and tax basis of
assets and liabilities as measured by the enacted tax rates. A valuation
allowance must be established for any portion of a deferred tax asset for which
it is more likely than not that a tax benefit will not be realized.
Statement of Cash Flows
The Company considers all highly liquid debt instruments purchased
with an original maturity of three months or less to be cash equivalents. These
investments earned 4.4 and 5.9 percent rates of interest at December 31, 1998
and 1997, respectively, with cost approximating market.
-24-
<PAGE>
KEY PRODUCTION COMPANY, INC.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Fair Value of Financial Instruments
The Company's financial investments consist of cash, trade receivables,
trade payables and long-term debt. The carrying value of cash and cash
equivalents, trade receivables and trade payables are considered to be
representative of their fair market value, due to the short maturity of these
instruments. The fair value of long-term debt is estimated based on current
rates available for similar debt with similar maturities and securities and
approximates its carrying value.
Reclassification
Certain prior year amounts have been reclassified to conform with the 1998
presentation.
Treasury Stock
The Company acquired treasury shares in 1998, 1997 and 1996. Treasury
Stock is recorded at acquisition cost.
-25-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. ACQUISITIONS
In December 1998, Key purchased EEX Corporation's (EEX) remaining interest
in oil and gas properties in the Hardeman Basin of north-central Texas for $10.5
million. In September 1997, Key purchased 20 percent of EEX's interest and
assumed operation of the producing properties. Acquisition of other producing
and non-producing properties in 1998 totaled $2.7 million.
Key made various property acquisitions in 1997 including the acquisition of
non-producing acreage over 11 salt domes in west-central Mississippi.
Key consummated the acquisition of Brock Exploration Corporation (Brock) on
March 28, 1996 in a tax-free reorganization pursuant to which Brock became a
wholly-owned subsidiary of Key. To effect the transaction, each Brock
shareholder received one share of Key common stock for each 1.45 Brock shares
held.
2. DEBT
Bank Financing-The bank financing is a revolving credit facility with
NationsBank of Texas, N.A. (the Bank). The Company entered into the Credit
Agreement (Agreement) on April 25, 1994, to fund acquisitions and drilling
opportunities. In 1998, the Company executed an amendment to the Agreement that
increased the maximum loan amount from $50 million to $75 million.
The borrowing base elected by the Company was $70 million at the end of
1998, an increase from the $42 million base in effect at year-end 1997. Semi-
annually, the Bank determines the maximum allowable borrowing base. The amount
of the borrowing base is determined, at the Bank's discretion, by the value it
assigns to the oil and gas properties of the Company less any outstanding debt.
The Bank may also consider other credit factors such as assets, liabilities,
cash flow, properties, prospects, management and ownership. If the re-
determined borrowing base falls below the balance of outstanding borrowings, the
Bank may request repayment of the excess amount.
Interest on amounts borrowed is charged at NationsBank's prime rate or at
London Interbank Offered Rates (LIBOR) plus .5 to 1.125 percent, at the
Company's option. The factor added to LIBOR is determined by the Company's debt
to capitalization ratio at the time of borrowing. The average interest rate on
the various maturities of debt outstanding at December 31, 1998, was 6.03
percent. Key pays a .25 percent fee on the unused portion of the borrowing
base, as well as other fees of approximately $10,000 per year in return for the
Bank's commitment to maintain the availability of those funds. On April 1,
2000, the borrowing converts from a revolving loan to a term note. At that
point, if not renegotiated before then, the Company must commence quarterly
principal payments in addition to paying interest. The entire facility matures
on January 1, 2003. The conversion and maturity dates are based on the Second
Amendment to the Credit Amendment made on April 15, 1998.
The credit facility requires the Company to comply with certain covenants
contained within the Agreement until full and final payment of the obligation
and termination of the Agreement. The Company has been in compliance with the
covenants since inception of the Agreement.
-26-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Aggregate maturities of long-term debt outstanding at December 31, 1998,
are as follows:
<TABLE>
<CAPTION>
(In thousands)
<S> <C>
1999 $ -
2000 15,000
2001 20,000
2002 20,000
2003 5,000
Thereafter -
--------
$ 60,000
========
</TABLE>
3. INCOME TAXES
Deferred tax assets and liabilities are comprised of the following components
at December 31, 1998 and 1997:
<TABLE>
<CAPTION>
1998 1997
-------- --------
(In thousands)
<S> <C> <C>
Long-term deferred tax assets:
Operating loss carryforwards $ 5,241 $ 4,104
Percentage depletion carryforwards 826 826
Other 925 59
-------- --------
6,992 4,989
Valuation allowance.......................................................................................... (2,088) (2,233)
-------- --------
4,904 2,756
Long-term deferred tax liabilities:
Depreciation, depletion and amortization.................................................................... (23,027) (18,459)
-------- --------
Net deferred income tax liability........................................................................... $(18,123) $(15,703)
======== ========
</TABLE>
The Company had net tax operating loss carryforwards of approximately $14.4
million at December 31, 1998, which expire in the years 1998 through 2010. As
of December 31, 1998, a portion of these net operating losses (NOLs) acquired as
part of the Brock acquisition are subject to annual limitations. The Company
has provided a valuation allowance for the portion of these NOLs which it does
not believe will be available for use prior to expiration.
Income tax expense consisted of the following:
<TABLE>
<CAPTION>
For the Year Ended December 31,
-------------------------------
1998 1997 1996
----- ------ ------
(In thousands)
<S> <C> <C> <C>
Current Taxes:
Federal........................ $ - $ - $ 37
State.......................... 297 - -
Deferred Taxes................... 2,520 5,943 4,854
------ ------ ------
Total tax provision on income $2,817 $5,943 $4,891
====== ====== ======
</TABLE>
-27-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
A reconciliation of the statutory income tax rate to the effective rate is
as follows:
<TABLE>
<CAPTION>
1998 1997 1996
---- ---- ----
<S> <C> <C> <C>
Statutory income tax rate.......................... 34.0% 34.0% 34.0%
State income tax................................... 4.0 4.0 4.0
------ ----- -----
38.0% 38.0% 38.0%
====== ===== =====
</TABLE>
4. NON-CASH INVESTING AND FINANCING ACTIVITIES
Supplemental Disclosure of Cash Flow Information
<TABLE>
<CAPTION>
For the Year Ended December 31,
-------------------------------
1998 1997 1996
------ ----- -----
(In thousands)
<S> <C> <C> <C>
Cash paid during the year for:
Interest (net of amounts
capitalized) $1,144 $ 987 $ 537
Income taxes (net of refunds
received) $ (147) $ 145 $ 245
</TABLE>
Supplemental Schedule of Non-Cash-Investing and Financing Activities
In connection with the Brock acquisition, the Company received cash and
cash equivalents totaling $2,098,000. In addition to the cash impact, the
acquisition had the following non-cash impact on the Company's December 31, 1996
balance sheet:
<TABLE>
<CAPTION>
Amount
--------------
(In thousands)
<S> <C>
Current assets $ 1,383
Oil and gas properties 21,346
-------
$22,729
=======
Current liabilities $ 1,099
Long-term debt 7,950
Non-current liabilities 1,909
Stockholders' equity 13,869
-------
$24,827
=======
</TABLE>
5. STOCK OPTIONS
The Key Production Company, Inc. 1992 Stock Option Plan reserves 2,000,000
shares of common stock for issuance to the Company's officers and employees. A
total of 887,500 options were outstanding at year-end. The options expire at
various dates through 2007 and are at prices ranging from $2.50 to $11.38 per
share with an aggregate exercise price of $8,472,531.
The Key Production Company, Inc. Stock Option Plan for Non-Employee
Directors reserves 360,000 shares of common stock for issuance to the Company's
non-employee directors. There were 152,500 options outstanding at year-end at
an aggregate exercise price of $1,230,938. These outstanding options were
granted at exercise prices from $2.88 to $12.00 and expire at various dates
through 2008.
-28-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
The Company's president was granted options for 500,000 shares of the
Company's common stock in 1992 in accordance with the terms of his employment
agreement. These outstanding options were granted at an exercise price of $3.00
and expire in 2002.
All options granted had an exercise price equal to or above market price on
the date of grant. Subject to accelerated vesting under certain circumstances
such as death of the employee or change in control of the Company, one-third of
the options vest in each of the three years following the date of grant.
The following table summarizes the changes in stock options for the year,
the number of common shares available for grant and the number of outstanding
options vested at year-end.
<TABLE>
<CAPTION>
1998
--------------------
Weighted
Average
Number of Exercise
Options Price
---------- --------
<S> <C> <C>
Outstanding, Beginning of Year.... 1,479,500 $ 6.07
Granted........................... 62,500 $11.75
Exercised......................... (2,000) $ 4.13
---------
Outstanding, End of Year.......... 1,540,000 $ 6.30
=========
Exercisable, End of Year.......... 1,129,167 $ 4.48
=========
Available for Grant, End of Year.. 1,162,500
=========
<CAPTION>
1997
--------------------
Weighted
Average
Number of Exercise
Options Price
--------- --------
<S> <C> <C>
Outstanding, Beginning of Year.... 1,049,000 $ 3.32
Granted........................... 500,000 $11.38
Exercised......................... (69,500) $ 2.85
---------
Outstanding, End of Year.......... 1,479,500 $ 6.07
=========
Exercisable, End of Year.......... 942,833 $ 3.19
=========
Available for Grant, End of Year.. 1,225,000
=========
<CAPTION>
1996
--------------------
Weighted
Average
Number of Exercise
Options Price
--------- --------
<S> <C> <C>
Outstanding, Beginning of Year.... 1,090,000 $ 3.08
Granted........................... 45,000 $ 8.13
Exercised......................... (86,000) $ 2.75
---------
Outstanding, End of Year 1,049,000 $ 3.32
=========
Exercisable, End of Year.......... 925,667 $ 3.06
=========
Available for Grant, End of Year.. 545,000
=========
</TABLE>
-29-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Statement of Financial Accounting Standards No. 123, "Accounting for Stock-
Based Compensation" (SFAS No. 123) was adopted by the Company as of December 31,
1996. This Statement defines a fair value based method of accounting for
employee stock options or similar equity instruments. However, SFAS No. 123
allows the continued measurement of compensation cost for such plans using the
intrinsic value based method prescribed by APB Opinion No. 25, "Accounting for
Stock Issued to Employees" (APB No. 25), provided that pro forma results of
operations are disclosed for those options granted beginning January 1, 1995.
The Company has elected to account for stock-based compensation plans under APB
No. 25, under which no compensation expense has been recognized for stock option
grants in 1998, 1997 and 1996. If the accounting provision of SFAS No. 123 had
been adopted in 1995, the Company would have reported 1998 pro forma net income
of $4.0 million, basic earnings of $.35 per share and diluted earnings of $.33
per share. For 1997, the Company would have reported pro forma net income of
$9.1 million, basic earnings of $.80 per share and diluted earnings of $.75 per
share. Pro forma information is not presented for 1996 because the effect on
net earnings would have been immaterial.
The weighted-average fair value of each option granted is estimated on the
date of grant using the Black Scholes option pricing model with the following
assumptions for 1998: risk-free interest rate of 5.6 to 6.8 percent, expected
weighted-average lives of five years, expected volatility of 39 percent in 1996
and 1997 and 47 percent in 1998 and expected dividends of zero percent.
The following table summarizes information about the stock options outstanding
at December 31, 1998:
<TABLE>
<CAPTION>
Options Outstanding Options Exercisable
--------------------- -------------------------------
Weighted
Average Weighted Weighted
Range of Remaining Average Average
Year Exercise Number Contractual Exercise Number Exercise
Granted Prices Outstanding Life Price Exercisable Price
- ----------- ------------- ----------- ----------- -------- ----------- -------------------
<S> <C> <C> <C> <C> <C> <C>
1992-1993 $ 2.50-$3.75 724,000 3.9 years $ 3.01 724,000 $ 3.01
1994-1995 $ 3.00-$4.88 208,500 5.3 years $ 3.53 208,500 $ 3.53
1996-1997 $ 8.13-$11.38 545,000 8.0 years $11.11 196,667 $10.88
1998 $11.31-$12.00 62,500 9.3 years $11.75 - -
--------- ----------- ------ --------- ------
1,540,000 5.8 years $ 6.30 1,129,167 $ 4.48
========= =========== ====== ========= ======
</TABLE>
6. EMPLOYEE BENEFIT PLANS
Retirement Plan-The Company provides a 401(k) retirement/savings plan for
all employees. This plan allows participants to contribute up to 10 percent of
their compensation, with Key matching contributions up to a maximum of 4 percent
of their compensation. The Company's contribution is made in the form of Key
common stock. Employees vest in the Company's contribution at the rate of 25
percent per year. Total expenses for the Company's matching contribution were
$169,714, $114,109 and $78,877 in 1998, 1997 and 1996 respectively.
-30-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Deferred Compensation Plan-Effective December 1, 1993, the Company
established the Key Production Company, Inc. Deferred Compensation Plan. This
plan is intended to provide a mechanism whereby certain management employees of
the Company may defer compensation. The Company intends for this plan to
provide the eligible employees with the opportunity to defer compensation in
cases where deferrals under the 401(k) plan may be limited by applicable
provisions of the Internal Revenue Code of 1986.
Income Continuance Plan-Effective June 1, 1994, the Company established the
Key Production Company, Inc. Income Continuance Plan. The plan provides for the
continuation of salary and benefits for certain employees in the event of a
change in control of the Company.
The administrative, compliance and legal costs associated with
administering these plans are paid by Key. Such expenses were not significant
in 1998, 1997, or 1996.
7. COMMITMENTS AND CONTINGENCIES
Lease Commitments-The Company has leases for office space with varying
expiration dates through 2002. Rental expense was $407,039, $262,648 and
$138,858 for 1998, 1997 and 1996, respectively.
As of December 31, 1998, minimum rental commitments under these leases are
payable in the following years:
1999 $364,848
2000 303,814
2001 289,155
2002 39,674
--------
$997,491
========
Litigation-The Company is involved in litigation claims and is subject to
governmental and regulatory controls arising in the ordinary course of business.
It is the opinion of the Company's management that all claims and litigation
involving the Company are not likely to have a material adverse effect on its
financial position, results of operation or cash flows.
Environmental-The Company is not aware of any environmental claims existing
as of December 31, 1998, which would have a material impact upon the Company's
financial condition, results of operations or cash flows. Key does not believe
that compliance with federal, state or local provisions regulating the discharge
of materials into the environment, or otherwise relating to the protection of
the environment, will have such an impact on the future.
8. TRANSACTIONS WITH RELATED PARTIES
In October 1996, the Company purchased 224,022 shares of Key common stock
from Lawrence Brock for $10.00 per share, the then current market price. Mr.
Brock was the chairman and chief executive officer of Brock at the time Brock
was acquired by the Company. The purchase was funded using the Company's
existing credit facility.
-31-
<PAGE>
KEY PRODUCTION COMPANY, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
In May 1997, the Company purchased 40,000 shares of Key common stock from
Janet Moylan, widow of Tim Moylan. Mr. Moylan was a director of Key from 1993
to 1996. The shares were purchased at $10.00 per share, which was the market
price at that time.
9. CONCENTRATION OF CREDIT RISK
Substantially all of the Company's accounts receivable at December 31, 1998
and 1997, resulted from transactions with other companies in the oil and gas
industry. This concentration of customers may impact the Company's overall
credit risk, either positively or negatively, in that these entities may be
similarly affected by industry-wide changes in economic or other conditions.
Such receivables are generally not collateralized.
The following parties purchased 10 percent or more of Key's oil and gas
production:
<TABLE>
<CAPTION>
For the Year Ended December 31,
-------------------------------
Purchaser 1998 1997 1996
--------- ----- ----- -----
<S> <C> <C> <C>
Eighty Eight Oil Company...... 6% 12% 16%
ProEnergy Marketing........... 11% 14% 16%
Transok, LLC.................. 21% 14% -
Enserco Energy, Inc........... 13% - -
Tosco Refining & Marketing.... 14% - -
Scurlock Permian Corporation.. 22% - -
</TABLE>
Effective January 1, 1993, Key entered into an agreement with Apache
Corporation (Apache) under which Key paid Apache a fee to market the majority of
its gas production that was not subject to traditional gas contract
arrangements. From 1993 to March 1996, the majority of Key's gas production
marketed by Apache was sold to Natural Gas Clearinghouse. Effective April 1996,
a portion of Key's gas production previously marketed by Apache was sold to
ProEnergy. Beginning January 1997, Key signed a five-year agreement with
Transok, LLC. Under this arrangement, Transok, LLC will gather and purchase the
majority of Key's Mid-Continent gas production.
10. EARNINGS PER SHARE
Basic earnings per share is computed based on the monthly weighted-average
number of shares outstanding during the periods. The weighted-average number of
common shares used in computing basic earnings per share was 11,508,628,
11,480,071 and 10,924,845 for 1998, 1997 and 1996, respectively. Diluted
earnings per share is computed based on the monthly weighted-average number of
common stock equivalents (stock options) using the treasury stock method.
Dilutive common stock equivalents assumed to have been exercised totaled
631,631, 688,818 and 621,355 for 1998, 1997 and 1996, respectively.
-32-
<PAGE>
KEY PRODUCTION COMPANY, INC.
SUPPLEMENTAL OIL AND GAS DISCLOSURES
Oil and Gas Operations-The following tables contain revenues and direct
cost information relating to the Company's oil and gas exploration and
production activities for the periods indicated. Key has no long-term supply or
purchase agreements with governments or authorities in which it acts as
producer.
<TABLE>
<CAPTION>
For the Year Ended December 31,
-------------------------------
1998 1997 1996
------ -------- -----
(In thousands, except percentages)
<S> <C> <C> <C>
Oil and gas revenues from production....... 37,413 $41,965 $37,553
------ ------- -------
Operating costs:
Depreciation, depletion and amortization.. 15,833 12,978 12,521
Lease operating........................... 8,874 7,913 7,325
Production taxes.......................... 2,409 2,714 2,314
Income taxes.............................. 3,913 6,977 5,849
------ ------- ------
31,029 30,582 28,009
------ ------- ------
Results of operations from oil and gas
producing activities...................... $6,384 $11,383 $9,544
====== ======= ======
Amortization rate as a percentage
of revenues............................... 42.3% 30.9% 33.3%
===== ======= =====
</TABLE>
Capitalized Costs-The following table sets forth the capitalized costs and
related accumulated depreciation, depletion and amortization relating to the
Company's oil and gas production, exploration and development activities.
<TABLE>
<CAPTION>
For the Year Ended December 31,
----------------------------------
1998 1997 1996
----------- ---------- ---------
(In thousands)
<S> <C> <C> <C>
Balance, beginning of year.................. $157,071 $113,172 $ 70,574
Costs incurred during the year:
Exploration:
Evaluated................................ 6,952 6,444 6,613
Unevaluated.............................. 3,683 4,160 1,056
Development................................ 31,541 26,115 12,834
Acquisition of properties:
Proved................................... 9,605 3,763 22,283
Unproved................................. 3,648 4,143 690
Property sales:
Proved................................... (733) (361) (713)
Unproved................................. (2,678) (365) (165)
-------- -------- --------
Balance, end of year........................ 209,089 157,071 113,172
Less - costs not being amortized............ (23,276) (18,624) (10,685)
-------- -------- --------
Costs being amortized....................... 185,813 138,447 102,487
Less - accumulated depreciation, depletion
and amortization........................... (57,752) (41,919) (28,941)
-------- -------- --------
Capitalized costs being amortized, net...... $128,061 $ 96,528 $ 73,546
======== ======== ========
</TABLE>
Costs Not Being Amortized-Oil and gas property costs not being amortized at
December 31, 1998, totaled $23,276,000. Of the total, $12,450,000, $6,895,000,
$795,000, $577,000, and $2,559,000 was incurred in 1998, 1997, 1996, 1995 and
1994,
-33-
<PAGE>
respectively. The Company expects a majority of these costs to be evaluated and
to become subject to amortization within the next three years.
Oil and Gas Reserve Information (Unaudited)-Proved oil and gas reserve
quantities are based on estimates prepared by the Company's engineers, and were
audited by Ryder Scott Company Petroleum Engineers, independent petroleum
engineers, in accordance with guidelines established by the Securities and
Exchange Commission (SEC). Reserve estimates are based on economic and
operating conditions existing at December 31 of each year presented.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and projecting future rates of production and the timing of
development expenditures. The following reserve data represents estimates only
and should not be construed as being exact. All of the Company's reserves are
located in the continental or offshore United States.
<TABLE>
<CAPTION>
Gas in Million Cubic Feet Oil in Thousands of Barrels
------------------------------------ ------------------------------
1998 1997 1996 1998 1997 1996
------------- ------------ ------- --------- --------- --------
<S> <C> <C> <C> <C> <C> <C>
Total proved reserves-
Developed and undeveloped
Beginning of year........ 69,543 64,094 37,478 6,213 6,207 3,792
Revisions of previous
estimates............... 8,523 (1,206) 1,289 (282) (306) 410
Improved recovery........ - - 27 - 5 165
Extensions and
discoveries............. 16,560 17,401 13,675 910 845 242
Purchases of
reserves................ 971 374 21,107 1,159 301 2,457
Production............... (12,600) (10,958) (9,198) (965) (839) (853)
Sales of properties...... (41) (162) (284) (13) - (6)
------- ------- ------ ----- ----- -----
End of year.............. 82,956 69,543 64,094 7,022 6,213 6,207
======= ======= ====== ===== ===== =====
Proved developed reserves-
Beginning of year........ 67,771 62,806 36,986 6,197 6,006 3,685
End of year.............. 82,337 67,771 62,806 7,012 6,197 6,006
</TABLE>
Future Net Cash Flows (Unaudited)-Future reserves are based on year-end
prices except in those instances where the sale of gas is covered by contract
terms providing for determinable escalations. Operating costs, production and
ad valorem taxes and future development costs are based on current costs with no
escalation.
The following table presents information concerning future net cash flows
from the production of oil and gas reserves, net of income tax expense. Income
tax expense has been computed using expected future tax rates and giving effect
to permanent differences and credits which, under current laws, relate to oil
and gas producing activities. This information does not purport to present the
fair market value of Key's oil and gas assets, but does present a standardized
disclosure concerning possible future net cash flows that will result under the
assumptions used.
-34-
<PAGE>
Discounted Future Net Cash Flows and Changes Relating to Proved Reserves at
December 31,
<TABLE>
<CAPTION>
1998 1997 1996
--------- --------- ----------
(In thousands)
<S> <C> <C> <C>
Cash inflows................................................................................ $252,148 $266,095 $ 380,765
Production and development costs............................................................ (82,031) (91,094) (115,224)
Income tax expense.......................................................................... (22,143) (34,171) (70,692)
-------- -------- ---------
Net cash flows.............................................................................. 147,974 140,830 194,849
10% annual discount rate.................................................................... (43,752) (41,577) (65,629)
-------- -------- ---------
Discounted future net cash flows............................................................ $104,222 $ 99,253 $ 129,220
======== ======== =========
The following are the principal sources of change in the discounted future net cash flows:
For the Year Ended December 31,
-------------------------------
1998 1997 1996
-------- -------- ---------
(In thousands)
Sales, net of production costs................................................................ $(26,130) $(31,338) $ (27,915)
Net change in prices and production........................................................... (27,302) (69,612) 42,155
Extensions, discoveries and improved
recovery, net of related costs............................................................... 30,580 36,531 33,267
Change in future development costs............................................................ 1,857 660 1,112
Revision of quantities........................................................................ 6,800 (2,432) 6,205
Accretion of discount......................................................................... 12,172 17,259 6,120
Change in income taxes........................................................................ 8,269 20,902 (32,920)
Purchases of reserves in place................................................................ 9,025 4,592 57,672
Sales of properties........................................................................... (155) (254) (238)
Change in production rates and other.......................................................... (10,147) (6,275) (6,996)
-------- -------- ---------
$ 4,969 $(29,967) $ 78,462
======== ======== =========
</TABLE>
Impact of Pricing (Unaudited)-The estimates of cash flows and reserve
quantities shown above are based on year-end oil and gas prices, except in those
cases where future gas sales are covered by contracts at specified prices.
Fluctuations are largely due to the seasonal pricing nature of natural gas,
supply perceptions for natural gas and significant worldwide volatility in oil
prices.
Under SEC rules, companies that follow full cost accounting methods are
required to make quarterly "ceiling test" calculations. Under this test,
capitalized costs of oil and gas properties may not exceed the present value of
estimated future net revenues from proved reserves, discounted at 10 percent,
plus the lower cost or fair market value of unproved properties, as adjusted for
related tax effects and deferred tax reserves. The Company calculates the
projected income tax effect using the "year-by-year" method for purposes of the
supplemental oil and gas disclosures and uses the "short-cut" method for the
"ceiling test" calculation. Application of these rules during periods of
relatively low oil and gas prices, even if of short-term duration, may result in
write-downs.
-35-
<PAGE>
UNAUDITED SUPPLEMENTAL QUARTERLY FINANCIAL DATA
<TABLE>
<CAPTION>
First Second Third Fourth Total
------- ------ ------ ------- -------
(In thousands, except for per share data)
<S> <C> <C> <C> <C> <C>
1998
- ----
Revenues.............. $ 9,811 $9,695 $9,059 $ 9,218 $37,783
Expenses, net......... 8,376 8,145 8,134 8,533 33,188
------- ------ ------ ------- -------
Net income............ $ 1,435 $1,550 $ 925 $ 685 $ 4,595
======= ====== ====== ======= =======
Basic earnings per
common share*........ $ .12 $ .13 $ .08 $ .06 $ .40
======= ====== ====== ======= =======
Diluted earnings per
common share*........ $ .12 $ .13 $ .08 $ .06 $ .38
======= ====== ====== ======= =======
1997
- ----
Revenues.............. $11,110 $9,516 $9,613 $11,912 $42,151
Expenses, net......... 8,240 7,473 7,613 9,129 32,455
------- ------ ------ ------- -------
Net income............ $ 2,870 $2,043 $2,000 $ 2,783 $ 9,696
======= ====== ====== ======= =======
Basic earnings per
common share......... $ .25 $ .18 $ .17 $ .24 $ .84
======= ====== ====== ======= =======
Diluted earnings per
common share......... $ .24 $ .17 $ .16 $ .23 $ .80
======= ====== ====== ======= =======
</TABLE>
* The sum of the individual quarters' net income per share may not agree with
year-to-date net income as each period's computation is based on the weighted
average number of shares outstanding during that period.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information set forth under the caption "Information About Nominees for
Election as Directors" in the Company's proxy statement relating to the
Company's 1999 annual meeting of stockholders (Proxy Statement) is incorporated
herein by reference. Certain information with regard to the executive officers
of the Company is set forth under the caption "Executive Officers of the
Registrant" in Part I of this report.
ITEM 11. EXECUTIVE COMPENSATION
The information set for the under the captions "Summary Compensation
Table," "Aggregated Option Exercises In The Last Fiscal Year and Fiscal Year-End
Option Values," "Director Compensation," and "Employment Agreements" in the
Proxy Statement is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information set forth under the captions "Security Ownership of Certain
Beneficial Owners" and "Security Ownership of Management" in the Proxy Statement
is incorporated herein by reference.
-36-
<PAGE>
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) 1. The following financial statements are included in Item 8 to this 10-K.
Statement of income for each of the three years in the period ended
December 31, 1998.
Statement of cash flows for each of the three years in the period ended
December 31, 1998.
Balance sheet as of December 31, 1998 and 1997.
Statement of changes in stockholders' equity for each of the three years in
the period ended December 31, 1998.
Summary of significant accounting policies.
Notes to financial statements.
Report of independent public accountants.
Supplemental oil and gas disclosures.
Supplemental quarterly financial data.
2. Schedules: None.
3. Exhibits:
Exhibits not incorporated by reference to a prior filing are designated by
an asterisk (*) and are filed herewith; all exhibits not so designated
are incorporated by reference to a prior SEC filing as indicated.
Exhibits designated by a plus sign (+) are management contracts or
compensatory plans or arrangements required to be filed herewith pursuant
to Item 14.
Exhibit No. Description
----------- -----------
2.1 -- Dissolution Agreement and Quitclaim Assignment between APC
Operating Partnership L.P., Apache Corporation and the
Registrant, dated as of January 1, 1993 (incorporated by
reference to Exhibit 2.1 to the Registrant's Form 10-Q for the
period ended March 31, 1993, file no. 0-17162).
2.2 -- Agreement and Plan of Merger dated as of December 21, 1995
among Key Production Company, Inc., Key Acquisition One, Inc.
and Brock Exploration Corporation (incorporated by reference
to Exhibit 2.2 to the Registrant's Statement on Form S-4,
-37-
<PAGE>
registration no. 333-00889 filed with the SEC on February 15,
1996).
3.1 -- Certificate of Incorporation of the Registrant (incorporated
by reference to Exhibit 3.1 to the Registrant's Registration
Statement on Form S-4, registration no. 33-23533 filed with
the SEC on August 5, 1988).
3.2 -- Amendment to Certificate of Incorporation of the Registrant
(incorporated by reference to Exhibit 3.2 to the Registrant's
Registration Statement on Form S-4, registration no. 33-23533
filed with the SEC on August 5, 1988).
3.3 -- Bylaws of the Registrant, as amended and restated on June 8,
1995 (incorporated by reference to Exhibit 3.3 to the
Registrant's Form 10-Q for the quarter ended June 30, 1995,
file no. 0-17162).
4.1 -- Form of Common Stock Certificate (incorporated by reference to
Exhibit 4.12 to the Registrant's Amendment No. 1 to
Registration Statement on Form S-4, registration no. 33-23533
filed with the SEC on August 15, 1988).
+ 10.7 -- Key Production Company, Inc. 1992 Stock Option Plan
(incorporated by reference to Exhibit 10.7 to the Registrant's
Form 10-K for the fiscal year ended December 31, 1992, file
no. 0-17162).
+ 10.8 -- Key Production Company, Inc. Stock Option Plan for Non-
Employee Directors, (incorporated by reference to Exhibit 10.8
to the Registrant's Form 10-K for the fiscal year ended
December 31, 1992, file no. 0-17162).
+ 10.9 -- Stock Option Agreement between the Registrant and Francis H.
Merelli, dated September 1, 1992 (incorporated by reference to
Exhibit 10.9 to the Registrant's Form 10-K for the fiscal year
ended December 31, 1992, file no. 0-17162).
+10.10 -- Key Production Company, Inc. 401(k) Plan (incorporated by
reference to Exhibit 10.10 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1992, file no. 0-17162).
+10.11 -- Employment Agreement between the Registrant and Francis H.
Merelli, dated as of September 1, 1992 (incorporated by
reference to Exhibit 10.11 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1992, file no. 0-17162).
+10.12 -- Employment Agreement between the Registrant and Monroe W.
Robertson, dated as of September 1, 1992 (incorporated by
reference to Exhibit 10.12 to the Registrant's Form 10-K for
the fiscal year ended December 31, 1992, file no. 0-17162).
10.16 -- Credit Agreement between Key Production Company, Inc. and
NationsBank of Texas, N.A., dated April 25, 1994 (incorporated
by reference to Exhibit 10.16 to the Registrant's Form 8-K
dated April 29, 1994, file no. 0-17162).
-38-
<PAGE>
+ 10.18 -- Key Production Company, Inc. Income Continuance Plan, dated
effective June 1, 1994 (incorporated by reference to Exhibit
10.18 to the Registrant's Form 10-K for the fiscal year ended
December 31, 1992, file no. 0-17162).
10.19 -- First Amendment to Credit Agreement between Key Production
Company, Inc. and NationsBank of Texas, N.A., dated January 1,
1997 (incorporated by reference to Exhibit 10.19 to the
Registrant's Form 10-K for the fiscal year ended December 31,
1996, file no. 0-17162).
10.20 -- Second Amendment to Credit Agreement between Key Production
Company, Inc. and NationsBank of Texas, N.A., dated April 15,
1998 (incorporated by reference to Exhibit 10.20 to the
Registrant's Form 10-Q for the period ended March 31, 1998,
file no. 0-17162).
+10.21.1 -- Amendment No. 1 to the Key Production Company, Inc. 1992 Stock
Option Plan, dated March 14, 1997 (incorporated by reference
to Exhibit 10.21.1 to the Registrant's Form 10-Q for the
period ended June 30, 1998, file no. 0-17162).
+10.21.2 -- Amendment No. 1 to the Key Production Company, Inc. Stock
Option Plan for Non-Employee Directors, dated January 27, 1997
(incorporated by reference to Exhibit 10.21.2 to the
Registrant's Form 10-Q for the period ended June 30, 1998,
file no. 0-17162).
+10.21.3 -- Amendment No. 2 to the Key Production Company, Inc. Stock
Option Plan for Non-Employee Directors, dated March 14, 1997
(incorporated by reference to Exhibit 10.21.3 to the
Registrant's Form 10-Q for the period ended June 30, 1998,
file no. 0-17162).
+10.21.4 -- Amendment No. 3 to the Key Production Company, Inc. Stock
Option Plan for Non-Employee Directors, dated May 7, 1998
(incorporated by reference to Exhibit 10.21.4 to the
Registrant's Form 10-Q for the period ended June 30, 1998,
file no. 0-17162).
* 23.1 -- Consent of Arthur Andersen LLP, dated March 23, 1999.
* 27.1 -- Financial Data Schedule for Commercial and Industrial
Companies per Article 5 of Regulation S-X for the year ended
December 31, 1998.
(b) Reports on Form 8-K:
No reports on Form 8-K were filed during the quarter ended December 31,
1998.
-39-
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned thereunto duly authorized:
KEY PRODUCTION COMPANY, INC.
By: /s/ F.H. Merelli
-----------------
F.H. Merelli
Date: March 24, 1999 Chairman, President and Chief
-------------- Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
Signature Title Date
--------- ----- ----
/s/ F.H. Merelli Director, Chairman, President
---------------- and Chief Executive Officer
F.H. Merelli (Principal Executive Officer) March 24, 1999
--------------
/s/ Monroe W. Robertson Senior Vice President
----------------------- and Secretary
Monroe W. Robertson (Principal Financial Officer) March 24, 1999
--------------
/s/ Cathy L. Anderson Controller
--------------------- (Principal Accounting Officer) March 24, 1999
Cathy L. Anderson --------------
/s/ Cortlandt S. Dietler Director March 24, 1999
------------------------ --------------
Cortlandt S. Dietler
/s/ L. Paul Teague Director March 24, 1999
------------------ --------------
L. Paul Teague
-40-
<PAGE>
Exhibit 23.1
CONSENT OF INDEPENDENT PUBLIC ACCOUNTANTS
As independent public accountants, we hereby consent to the incorporation of
our report included in this Form 10-K into Key Production Company, Inc.'s
previously filed Registration Statement on Form S-8, dated September 5, 1995,
file No. 33-62355.
Arthur Andersen LLP
Denver, Colorado,
March 23, 1999.
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