<PAGE> 1
FILED PURSUANT TO RULE 424 (b)(1)
REGISTRATION NO. 333-14835
PROSPECTUS
5,795,000 SHARES
[COMSTOCK LOGO]
COMMON STOCK
------------------
Of the 5,795,000 shares of Common Stock offered hereby (the "Offering"),
4,000,000 shares are being sold by Comstock Resources, Inc. (the "Company") and
1,795,000 shares are being sold by certain stockholders (the "Selling
Stockholders"). See "Principal and Selling Stockholders." The Company will not
receive any of the proceeds from the sale of shares by the Selling Stockholders.
The Common Stock is quoted on The Nasdaq Stock Market's National Market
(the "Nasdaq National Market") under the symbol "CMRE." The last reported sale
price of the Common Stock on the Nasdaq National Market was $12.875 per share on
November 25, 1996. See "Price Range of Common Stock."
SEE "RISK FACTORS" BEGINNING ON PAGE 8 FOR A DISCUSSION OF CERTAIN FACTORS
THAT SHOULD BE CONSIDERED BY PROSPECTIVE PURCHASERS OF THE COMMON STOCK OFFERED
HEREBY.
------------------
THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES AND
EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION NOR HAS THE
SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES
COMMISSION PASSED UPON THE ACCURACY OR ADEQUACY OF THIS
PROSPECTUS. ANY REPRESENTATION TO THE CONTRARY IS A
CRIMINAL OFFENSE.
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
UNDERWRITING PROCEEDS TO
PRICE TO DISCOUNTS AND PROCEEDS TO SELLING
PUBLIC COMMISSIONS(1) COMPANY(2) STOCKHOLDERS
=====================================================================================================
<S> <C> <C> <C> <C>
Per Share $12.50 $0.625 $11.875 $11.875
- -----------------------------------------------------------------------------------------------------
Total(3) $72,437,500 $3,621,875 $47,500,000 $21,315,625
=====================================================================================================
</TABLE>
(1) For information regarding indemnification of the Underwriters, see
"Underwriting."
(2) Before deducting estimated expenses of $500,000 payable by the Company.
(3) The Company has granted to the Underwriters a 30-day option to purchase
up to 869,250 additional shares of Common Stock on the same terms as set
forth above solely to cover over-allotments, if any. See "Underwriting."
If the Underwriters exercise this option in full, the total Price to
Public, Underwriting Discounts and Commissions and Proceeds to Company
will be $83,303,125, $4,165,156 and $57,822,344, respectively.
------------------
The shares of Common Stock are being offered by the several Underwriters
named herein, subject to prior sale, when, as and if delivered to and accepted
by them and subject to certain conditions. It is expected that certificates for
the shares of Common Stock offered hereby will be available for delivery on or
about December 2, 1996, at the office of Smith Barney Inc., 333 West 34th
Street, New York, New York 10001.
SMITH BARNEY INC. RAYMOND JAMES & ASSOCIATES, INC.
BEAR, STEARNS & CO. INC.
OPPENHEIMER & CO., INC.
RODMAN & RENSHAW, INC.
November 25, 1996
<PAGE> 2
[Map of Texas and Louisiana showing the Company's major oil and gas properties.]
IN CONNECTION WITH THIS OFFERING, THE UNDERWRITERS MAY OVER-ALLOT OR EFFECT
TRANSACTIONS WHICH STABILIZE OR MAINTAIN THE MARKET PRICE OF THE COMMON STOCK OF
THE COMPANY AT A LEVEL ABOVE THAT WHICH MIGHT OTHERWISE PREVAIL IN THE OPEN
MARKET. SUCH TRANSACTIONS MAY BE EFFECTED ON THE NASDAQ NATIONAL MARKET, IN THE
OVER-THE-COUNTER MARKET, OR OTHERWISE. SUCH STABILIZING, IF COMMENCED, MAY BE
DISCONTINUED AT ANY TIME.
IN CONNECTION WITH THIS OFFERING, THE UNDERWRITERS MAY ENGAGE IN PASSIVE
MARKET-MAKING TRANSACTIONS IN THE COMMON STOCK OF THE COMPANY ON THE NASDAQ
NATIONAL MARKET IN ACCORDANCE WITH RULE 10B-6A UNDER THE SECURITIES EXCHANGE ACT
OF 1934. SEE "UNDERWRITING."
2
<PAGE> 3
PROSPECTUS SUMMARY
The following summary is qualified in its entirety by the more detailed
information and financial statements and notes thereto set forth elsewhere in
this Prospectus or incorporated by reference herein. As used herein, the term
"Company" means Comstock Resources, Inc., its predecessor and its subsidiaries,
except as the context may otherwise require. Unless otherwise indicated, the
information contained herein gives pro forma effect to the 1995 Acquisitions and
the 1996 Transactions as described in "Pro Forma Financial Information" and
assumes that the Underwriters' over-allotment option will not be exercised. The
estimated proved reserve information included or incorporated in this Prospectus
is based on reports prepared by Lee Keeling and Associates, Inc., independent
petroleum consultants. Certain oil and gas terms used in this Prospectus are
defined in the "Glossary" included herein.
THE COMPANY
GENERAL
Comstock Resources, Inc. is an independent energy company engaged in the
acquisition, development, production and exploration of oil and natural gas
properties. The Company is also engaged in the gathering, processing and
marketing of natural gas. As of December 31, 1995, the Company had pro forma
proved reserves of 307.9 Bcfe with an estimated Present Value of Proved Reserves
of $286.4 million. On a Bcfe basis, these reserves were 83% natural gas and 74%
proved developed. The Company believes that its primary strengths include (i)
its ability to acquire oil and natural gas properties at attractive costs, (ii)
its high quality, long-lived reserve base, of which 92% is concentrated in
Southeast Texas, East Texas/North Louisiana and the Texas Gulf Coast, and (iii)
its ability to efficiently operate and develop its oil and natural gas
properties.
The Company has grown primarily through the acquisition of producing
properties. Since 1991 the Company has added 286.8 Bcf of natural gas and 10.5
MMBbls of oil from 16 acquisitions at a total cost of $225.5 million, or $0.64
per Mcfe. The Company's two largest acquisitions to date have been its purchase
of properties from Sonat Inc. in July 1995 for $50.6 million (the "Sonat
Acquisition") and its acquisition of Black Stone Oil Company and interests in
the Double A Wells field in May 1996 for $104.0 million (the "Black Stone
Acquisition"). Primarily as a result of the Company's acquisition activities,
(i) average net daily production increased from 27.9 MMcfe in 1993 to 78.9 MMcfe
on a pro forma basis for the nine months ended September 30, 1996 and (ii)
EBITDA (as defined) increased from $13.9 million for 1993 to $37.1 million on a
pro forma basis for 1995. EBITDA on a pro forma basis for the first nine months
of 1996 was $47.6 million.
While continuing to pursue attractive acquisitions, the Company has
recently increased its focus on the exploitation and development of its existing
properties through the implementation of operational improvements, workovers,
recompletions and the drilling of development and exploratory wells. During 1995
and the first nine months of 1996, the Company spent $3.7 million and $6.3
million, respectively, on development and exploration activities. As part of its
increased emphasis on such activities, the Company anticipates spending in
excess of $20.0 million on currently identified development and exploration
projects in the fourth quarter of 1996 through 1997.
BUSINESS STRATEGY
The Company's strategy is to increase cash flow and net asset value by
acquiring oil and natural gas properties at attractive costs and developing its
reserves. In addition, the Company intends to pursue selective exploration
opportunities in its core operating areas. The key elements of the Company's
business strategy are to:
3
<PAGE> 4
ACQUIRE HIGH QUALITY PROPERTIES AT ATTRACTIVE COSTS
The Company has a successful track record of increasing its reserves
through opportunistic acquisitions. The Company applies strict economic and
reserve risk criteria in evaluating acquisitions and targets properties with
established production where it can obtain operational control and increase
production and reserves through exploitation activities. The Black Stone
Acquisition and the Sonat Acquisition have significant development and
exploration potential and were acquired at costs equal to 70% and 68%,
respectively, of their estimated Present Value of Proved Reserves. Due to its
experience in its core operating areas, the Company believes it is better able
to identify and evaluate potential acquisitions and negotiate and close selected
acquisitions on favorable terms.
OPERATE PROPERTIES
The Company prefers to operate the properties it acquires, allowing it to
exercise greater control over the timing and plans for future development, the
level of drilling and lifting costs, and the marketing of production. The
Company operates properties comprising approximately 85% of its pro forma
Present Value of Proved Reserves as of December 31, 1995.
MAINTAIN LOW COST STRUCTURE
The Company seeks to increase cash flow by carefully controlling operating
costs and general and administrative expense. The Company targets acquisitions
that possess, among other characteristics, low per unit operating costs. In
addition, the Company has been able to reduce per unit operating costs by
eliminating unnecessary field and corporate overhead costs and by divesting
properties that have high lifting costs with little future development
potential. Through these efforts, the Company's general and administrative
expense and average oil and gas operating costs per Mcfe have decreased from
$0.18 and $0.66, respectively, for 1993 to $0.08 and $0.49, respectively, on a
pro forma basis for the nine months ended September 30, 1996.
EXPLOIT EXISTING RESERVES
The Company seeks to maximize the value of its properties by increasing
production and recoverable reserves through active workover, recompletion and
exploitation activities. The Company utilizes advanced industry technology,
including 3-D seismic data, magnetic resonance imaging logging tools and newly
developed formation stimulation techniques. During the first nine months of
1996, the Company participated in the drilling of 14 development wells, and
plans to participate in 14 additional development wells during the fourth
quarter. The Company has identified 23 development wells to be drilled in 1997
and expects to drill additional wells based on drilling results and geologic
work in progress.
PURSUE SELECTIVE EXPLORATION OPPORTUNITIES
The Company pursues selective exploration activities to find additional
reserves on its undeveloped acreage and anticipates spending approximately 15%
of its 1997 drilling budget on exploration. The Company recently completed a 3-D
seismic survey in the East White Point field along the Texas Gulf Coast and
plans to drill an exploratory well in this field in the fourth quarter of 1996
and a deeper exploratory test well in the first quarter of 1997. In the West
Simsboro field in North Louisiana, the Company has completed a geological field
study and intends to drill an exploratory well to test an undeveloped fault
block by the end of 1996. The Company is also participating in the exploration
of undeveloped acreage adjacent to the Double A Wells field in Southeast Texas.
In 1997 the Company intends to participate in 3-D seismic surveys on its
offshore leases in the Gulf of Mexico.
4
<PAGE> 5
SIGNIFICANT ACQUISITIONS
BLACK STONE
In May 1996 the Company acquired, through a series of negotiated
transactions, 100% of the capital stock of Black Stone Oil Company and interests
in 19 producing wells (7.7 net) located in the Double A Wells field in Polk
County, Texas for $104.0 million. These high volume wells produce from the Upper
Woodbine formation at a total depth of approximately 14,500 feet. The Black
Stone Acquisition added proved reserves, as of January 1, 1996, of 5.3 MMBbls of
oil and 98.5 Bcf of natural gas, increasing the Company's reserve base by 67%.
The Company believes the field is in an early stage of its productive life. The
Company assumed operation of the field without incurring significant additional
overhead and has increased average daily production by 15% from April 1996, the
month prior to acquisition, to September 1996. The Company has initiated an
infill drilling program and is conducting exploration and field delineation
drilling activities on undeveloped acreage adjacent to the Double A Wells field.
SONAT
In July 1995 the Company purchased interests in certain producing oil and
gas properties and natural gas gathering systems located in East Texas and North
Louisiana from Sonat Inc. for $50.6 million. The acquired assets included
interests in 319 producing wells (188.0 net) along with interests in gas
gathering systems. The Sonat Acquisition included proved reserves of 0.8 MMBbls
of oil and 104.7 Bcf of natural gas. Since assuming operations, the Company has
been able to lower per unit operating costs for these properties by establishing
an efficient operating structure. A significant portion of the acquired reserves
are in the Travis Peak (Hosston in Louisiana) and Cotton Valley formations. The
majority of the Company's 1996 and 1997 infill drilling program is focused on
these properties.
THE OFFERING
<TABLE>
<S> <C>
Common Stock offered by the Company.............. 4,000,000 shares
Common Stock offered by the Selling 1,795,000 shares
Stockholders...................................
Common Stock to be outstanding after the 23,191,630 shares(1)
Offering.......................................
Use of proceeds.................................. To reduce outstanding indebtedness under
the Company's Bank Credit Facility. See
"Use of Proceeds."
Nasdaq National Market Symbol.................... CMRE
</TABLE>
- ---------------
(1) Excludes (i) 1,345,377 shares of Common Stock reserved for issuance upon the
conversion of outstanding shares of the Company's Series 1995 Convertible
Preferred Stock (the "Series 1995 Preferred") (after giving effect to the
issuance of 1,511,761 shares of Common Stock upon conversion of preferred
shares by certain Selling Stockholders in connection with the Offering) and
(ii) 2,937,680 shares of Common Stock reserved for issuance upon exercise of
outstanding stock options. See "Capitalization," "Management -- Compensation
of Executive Officers," "Principal and Selling Stockholders" and
"Description of Capital Stock."
5
<PAGE> 6
SUMMARY FINANCIAL INFORMATION
The following table sets forth certain historical and pro forma operating
and financial data of the Company. The historical data should be read in
conjunction with the Consolidated Financial Statements and the notes thereto
included elsewhere in this Prospectus. The Company acquired significant
producing oil and natural gas properties in all the periods presented which
affect the comparability of the historical financial and operating data for the
periods presented. The pro forma information should be read in conjunction with
the Pro Forma Financial Statements and notes thereto included elsewhere in this
Prospectus. The pro forma financial information for the year ended December 31,
1995 and for the nine months ended September 30, 1996 has been prepared as if
the 1995 Acquisitions, the 1996 Transactions and this Offering and the
application of the estimated net proceeds therefrom had occurred at the
beginning of the periods presented for purposes of the statement of operations
and other financial data. Neither the historical results nor the pro forma
results are necessarily indicative of the Company's future operations or
financial results. See "Selected Historical Financial Data," "Pro Forma
Financial Information" and "Management's Discussion and Analysis of Financial
Condition and Results of Operations."
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, NINE MONTHS ENDED SEPTEMBER 30,
--------------------------------------------- --------------------------------
PRO FORMA (UNAUDITED)
(UNAUDITED) PRO FORMA
1993 1994 1995 1995 1995 1996 1996
------- ------- -------- ----------- ------- -------- ---------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Revenues:
Oil and gas sales................... $21,805 $16,855 $ 22,091 $ 46,465 $14,254 $ 45,517 $ 55,999
Gas marketing, gathering and
processing........................ 107 15,029 50,678 51,247 35,240 68,114 68,114
Other............................... 541 770 2,899 2,970 2,814 1,961 1,961
------- ------- -------- -------- ------- -------- --------
Total revenues.................... 22,453 32,654 75,668 100,682 52,308 115,592 126,074
------- ------- -------- -------- ------- -------- --------
Expenses:
Oil and gas operating(1)............ 6,673 6,099 7,427 12,078 4,803 9,673 10,507
Gas marketing, gathering and
processing........................ 91 14,532 49,118 49,636 34,109 66,301 66,301
Exploration......................... 423 -- -- -- -- 285 285
Depreciation, depletion and
amortization...................... 8,334 7,390 8,613 17,500 6,114 12,809 16,082
General and administrative, net..... 1,834 1,823 1,979 1,910 1,448 1,546 1,705
Interest............................ 2,184 2,869 5,542 10,125 3,574 7,619 6,308
Impairment of oil and gas
properties(2)..................... -- -- 29,150 29,150 -- -- --
------- ------- -------- -------- ------- -------- --------
Total expenses.................... 19,539 32,713 101,829 120,399 50,048 98,233 101,188
------- ------- -------- -------- ------- -------- --------
Income (loss) before income taxes..... 2,914 (59) (26,161) (19,717) 2,260 17,359 24,886
------- ------- -------- -------- ------- -------- --------
Net income (loss) attributable to
common stock(3)..................... $ 2,741 $ (877) $(28,069) $ (20,063) $ 993 $ 15,612 $ 24,403
======= ======= ======== ======== ======= ======== ========
Net income (loss) per share: (3)
Primary............................. $ .25 $ (.07) $ (2.24) $ (.96) $ .08 $ 1.04 $ 1.02
======= ======= ======== ======== ======= ======== ========
Fully diluted....................... $ 0.82 $ 0.99
======== ========
OTHER FINANCIAL DATA:
EBITDA(4)............................. $13,855 $10,200 $ 17,144 $ 37,058 $11,948 $ 38,072 $ 47,561
Operating cash flow(5)................ 10,340 6,850 9,578 6,340 28,810
Capital expenditures.................. 21,779 16,386 61,809 59,708 106,668
</TABLE>
<TABLE>
<CAPTION>
AS OF DECEMBER 31, AS OF SEPTEMBER 30, 1996
------------------------------ --------------------------
1993 1994 1995 ACTUAL AS ADJUSTED(6)
------- ------- -------- -------- --------------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
BALANCE SHEET DATA:
Property and equipment, net.............................. $66,068 $77,989 $102,116 $188,233 $188,233
Total assets............................................. 74,095 91,571 120,099 222,383 222,383
Total debt............................................... 21,930 37,932 71,811 150,180 103,180
Stockholders' equity..................................... 27,646 41,205 30,128 48,950 95,950
</TABLE>
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(1) Includes lease operating costs and production and ad valorem taxes.
(2) Represents the impairment provision for the adoption of a new accounting
standard regarding the carrying value of long-lived assets.
(3) Before extraordinary losses of $417,000 in 1993 and $615,000 in 1994.
(4) As used in this Prospectus, EBITDA means income (loss) before income taxes,
plus interest, depreciation, depletion and amortization, impairment of oil
and gas properties and exploration.
(5) Represents cash flow provided by operations, before net changes in non-cash
working capital accounts.
(6) Adjusted to reflect the issuance of 1,511,761 shares of Common Stock upon
conversion of shares of Series 1995 Preferred and the sale by the Company of
4,000,000 shares of Common Stock in the Offering and the application of the
estimated net proceeds therefrom as described under "Use of Proceeds."
6
<PAGE> 7
SUMMARY RESERVE DATA
The following table summarizes the estimates of the Company's net proved
oil and natural gas reserves as of the dates indicated and the present value
attributable to these reserves at such dates based on reserve reports prepared
by Lee Keeling and Associates, Inc. For additional information relating to the
Company's oil and natural gas reserves, see "Risk Factors -- Uncertainties in
Estimating Reserves and Future Net Cash Flows," "Business and Properties -- Oil
and Natural Gas Reserves," the Supplemental Oil and Gas Information in the Notes
to the Consolidated Financial Statements of the Company included elsewhere in
this Prospectus and the summary report of Lee Keeling and Associates, Inc.
attached hereto as Appendix A.
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
--------------------------------------------
PRO
FORMA
1993 1994 1995 1995(1)
-------- -------- -------- --------
<S> <C> <C> <C> <C>
PROVED RESERVES:
Natural gas (MMcf)................................ 74,363 92,840 173,165 257,122
Oil (MBbls)....................................... 6,111 5,119 3,779 8,470
Total (MMcfe)..................................... 111,028 123,554 195,840 307,942
Present Value of Proved Reserves (000's).......... $ 60,952 $ 78,744 $148,292 $286,407
PROVED DEVELOPED RESERVES:
Natural gas (MMcf)................................ 42,909 62,827 130,375 189,899
Oil (MBbls)....................................... 1,655 1,504 2,562 6,198
Total (MMcfe)..................................... 52,838 71,851 145,750 227,086
</TABLE>
- ---------------
(1) Gives effect to the Black Stone Acquisition and the 1996 Dispositions as if
such transactions had been consummated as of December 31, 1995. See "Pro
Forma Financial Information."
SUMMARY OPERATING DATA
The following table sets forth certain summary operating data for the
Company for the periods indicated.
<TABLE>
<CAPTION>
NINE MONTHS ENDED
YEAR ENDED DECEMBER 31, SEPTEMBER 30,
-------------------------------------- ----------------------------
PRO FORMA PRO FORMA
1993 1994 1995 1995(1) 1995 1996 1996(2)
------- ------ ------- --------- ------ ------- ---------
<S> <C> <C> <C> <C> <C> <C> <C>
PRODUCTION:
Natural gas (MMcf)............. 8,514 6,514 9,297 18,866 6,198 13,651 16,475
Oil (MBbls).................... 278 263 356 877 236 650 842
Total (MMcfe).................. 10,184 8,090 11,430 24,126 7,616 17,550 21,529
Average daily production (MMcfe
per day).................... 27.9 22.2 31.3 66.1 27.9 64.3 78.9
AVERAGE SALES PRICES:
Natural gas (per Mcf).......... $ 2.03 $ 1.97 $ 1.73 $ 1.67 $ 1.66 $ 2.35 $ 2.34
Oil (per Bbl).................. 16.22 15.22 16.81 17.06 16.78 20.73 20.70
EXPENSES (PER MCFE):
Oil and gas operating(3)....... $0.66 $0.75 $0.65 $0.50 $0.63 $0.55 $0.49
General and administrative,
net......................... 0.18 0.23 0.17 0.08 0.19 0.09 0.08
Depreciation, depletion and
amortization(4)............. 0.78 0.88 0.72 0.71 0.77 0.71 0.73
</TABLE>
- ---------------
(1) Gives effect to the 1995 Acquisitions, the Black Stone Acquisition and the
1996 Dispositions as if such transactions had been consummated as of January
1, 1995. See "Pro Forma Financial Information."
(2) Gives effect to the Black Stone Acquisition and the 1996 Dispositions as if
such transactions had been consummated as of January 1, 1996. See "Pro Forma
Financial Information."
(3) Includes lease operating costs and production and ad valorem taxes.
(4) Represents depreciation, depletion and amortization of oil and gas
properties only.
7
<PAGE> 8
RISK FACTORS
In addition to other information set forth elsewhere in this Prospectus,
the following factors relating to the Company and the Offering should be
considered when evaluating an investment in the Common Stock offered hereby.
MARKET CONDITIONS AND VOLATILITY OF OIL AND NATURAL GAS PRICES
The revenues generated by the Company's operations are highly dependent
upon the prices of, and demand for, oil and natural gas. Historically, the
prices for oil and natural gas have been volatile and are likely to continue to
be volatile in the future. The Company is affected more by fluctuations in
natural gas prices than oil prices because a majority of its production is
natural gas (81% in 1995 on a natural gas equivalent basis). The prices received
by the Company for its oil and natural gas production and the level of such
production are subject to wide fluctuations and depend on numerous factors
beyond the Company's control, including seasonality, the condition of the United
States economy (particularly the manufacturing sector), imports of crude oil and
natural gas, political conditions in other oil-producing and natural
gas-producing countries, the actions of the Organization of Petroleum Exporting
Countries and domestic government regulation, legislation and policies.
Decreases in the prices of oil and natural gas have had, and could have in the
future, an adverse effect on the borrowing base under the Bank Credit Facility
(as defined), which would affect the Company's ability to borrow additional
funds. Although the Company is not currently experiencing any significant
involuntary curtailment of its natural gas production, market, economic and
regulatory factors may in the future materially affect the Company's ability to
sell its natural gas production.
In order to reduce its exposure to price risks in the marketing of its
natural gas production, the Company from time to time enters into natural gas
price swap arrangements to hedge a portion of its anticipated sales. Such
arrangements may also limit the ability of the Company to benefit from increases
in natural gas prices. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Results of Operations -- General."
ACQUISITION RISKS
The Company's rapid growth in recent years has been attributable in
significant part to acquisitions of producing properties. The Company expects to
continue to evaluate and, where appropriate, pursue acquisition opportunities on
terms management considers favorable to the Company. There can be no assurance
that suitable acquisition candidates will be identified in the future, or that
the Company will be able to finance such acquisitions on favorable terms. In
addition, the Company competes against other companies for acquisitions, and
there can be no assurance that the Company will be successful in the acquisition
of any material property interests. Further, there can be no assurances that any
future acquisitions made by the Company will be integrated successfully into the
Company's operations or will achieve desired profitability objectives.
The successful acquisition of producing properties requires an assessment
of recoverable reserves, exploration potential, future oil and natural gas
prices, operating costs, potential environmental and other liabilities and other
factors beyond the Company's control. In connection with such an assessment, the
Company performs a review of the subject properties that it believes to be
generally consistent with industry practices. Nonetheless, the resulting
assessments are necessarily inexact and their accuracy inherently uncertain, and
such a review may not reveal all existing or potential problems, nor will it
necessarily permit the Company to become sufficiently familiar with the
properties to fully assess their merits and deficiencies. Inspections may not
always be performed on every well, and structural and environmental problems are
not necessarily observable even when an inspection is undertaken.
Additionally, significant acquisitions can change the nature of the
operations and business of the Company depending upon the character of the
acquired properties, which may be substantially different in operating and
geologic characteristics or geographic location than existing properties. While
the Company's current operations are focused in Southeast Texas, East
Texas/North Louisiana and the Texas Gulf Coast, there is no assurance that the
Company will not pursue acquisitions or properties located in other geographic
areas.
8
<PAGE> 9
SUBSTANTIAL CAPITAL REQUIREMENTS
The Company makes, and will continue to make, substantial capital
expenditures for the acquisition, development and exploration of oil and gas
reserves. Historically, the Company has financed these expenditures primarily
with cash generated by operations, bank borrowings and the sale of equity
securities and non-strategic assets. The Company believes that it will have
sufficient cash provided by operating activities to fund anticipated 1996 and
1997 capital expenditures other than significant acquisitions. The Company
intends to borrow under the Bank Credit Facility or to obtain other debt or
equity financing as needed to finance future acquisitions. If revenues or the
Company's borrowing base decrease as a result of lower oil and natural gas
prices, operating difficulties or declines in reserves, the Company's ability to
obtain the capital necessary to undertake or complete future development
programs and to continue its acquisition activities may be limited. There can be
no assurance that additional debt or equity financing or cash generated by
operations will be available to meet these requirements. See "Management's
Discussion and Analysis of Financial Condition and Results of
Operations -- Liquidity and Capital Resources."
REPLACEMENT OF RESERVES
The Company's future success depends upon its ability to find, develop or
acquire additional oil and natural gas reserves that are economically
recoverable. The proved reserves of the Company will generally decline as
reserves are depleted, except to the extent that the Company conducts successful
exploration or development activities or acquires properties containing proved
reserves, or both. In order to increase reserves and production, the Company
must continue its development drilling and recompletion programs or undertake
other replacement activities. The Company's current strategy is to maintain its
focus on low-cost operations while increasing its reserve base, production and
cash flow through acquisitions of producing properties where the Company can
utilize its experience as a low-cost operator and use available cash flows to
continue to exploit its existing properties. There can be no assurance, however,
that the Company's planned development projects and acquisition activities will
result in significant additional reserves or that the Company will have
continuing success drilling productive wells at low finding and development
costs. Furthermore, while the Company's revenues may increase if prevailing oil
and natural gas prices increase significantly, the Company's finding costs for
additional reserves could also increase. For a discussion of the Company's
reserves, see "Business and Properties -- Oil and Natural Gas Reserves."
UNCERTAINTIES IN ESTIMATING RESERVES AND FUTURE NET CASH FLOWS
There are numerous uncertainties inherent in estimating quantities and
values of proved reserves and in projecting future rates of production and
timing of development expenditures, including many factors beyond the control of
the Company. Reserve engineering is a subjective process of estimating the
recovery from underground accumulations of oil and natural gas that cannot be
measured in an exact manner, and the accuracy of any reserve estimate is a
function of the quality of available data, of production history and of
engineering and geological interpretation and judgment. Because all reserve
estimates are to some degree speculative, the quantities of oil and natural gas
that are ultimately recovered, production and operating costs, the amount and
timing of future development expenditures and future oil and natural gas sales
prices may all differ materially from those assumed in these estimates. In
addition, different reserve engineers may make different estimates of reserve
quantities and cash flows based upon the same available data. The Present Value
of Proved Reserves set forth in this Prospectus represents estimates only and
should not be construed as the current market value of the estimated oil and
natural gas reserves attributable to the Company's properties. In this regard,
the information set forth in this Prospectus includes revisions of certain
reserve estimates attributable to proved properties included in the preceding
year's estimates. Such revisions reflect additional information from subsequent
activities, production history of the properties involved and any adjustments in
the projected economic life of such properties resulting from changes in product
prices. Any future downward revisions could adversely affect the Company's
financial condition, borrowing base under the Bank Credit Facility, future
prospects and the market value of its securities. See "Business and
Properties -- Oil and Natural Gas Reserves."
9
<PAGE> 10
DRILLING RISKS
Drilling activities are subject to many risks, including the risk that no
commercially productive reservoirs will be encountered. There can be no
assurance that new wells drilled by the Company will be productive or that the
Company will recover all or any portion of its investment. Drilling for oil and
natural gas may involve unprofitable efforts, not only from dry wells, but from
wells that are productive but do not produce sufficient net revenues to return a
profit after drilling, operating and other costs. The cost of drilling,
completing and operating wells is often uncertain. The Company's drilling
operations may be curtailed, delayed or canceled as a result of numerous
factors, many of which are beyond the Company's control, including title
problems, adverse weather conditions, compliance with governmental requirements
and shortages or delays in the delivery of equipment and services.
OPERATING HAZARDS AND UNINSURED RISKS
The Company's operations are subject to all of the risks normally incident
to the exploration for and the production of oil and natural gas, including
blowouts, cratering, oil spills and fires, each of which could result in damage
to or destruction of oil and natural gas wells, production facilities or other
property, or injury to persons. The Company anticipates that it will from time
to time conduct relatively deep drilling which will involve increased drilling
risks of high pressures and mechanical difficulties, including stuck pipe,
collapsed casing and separated cable. There can be no assurance that the levels
of insurance maintained by the Company will be adequate to cover any losses or
liabilities. The Company cannot predict the continued availability of insurance,
or availability at commercially acceptable premium levels.
COMPETITION
The oil and natural gas industry is highly competitive. The Company's
competitors for the acquisition, development and exploration of oil and natural
gas properties, purchases and marketing of natural gas and transportation and
processing of natural gas, and for capital to finance such activities, include
companies that have greater financial and personnel resources available to them
than the Company. The Company's ability to acquire additional properties and to
discover reserves in the future will be dependent upon its ability to evaluate
and select suitable properties and to consummate transactions in a highly
competitive environment. See "Business and Properties -- Competition."
GOVERNMENT REGULATION
The Company's business is affected by certain federal, state and local laws
and regulations relating to the development, production, marketing, pricing,
transportation and storage of oil and natural gas. The Company's business is
also subject to extensive and changing environmental and safety laws and
regulations governing plugging and abandonment of wells, the discharge of
materials into the environment or otherwise relating to environmental
protection. There can be no assurance that present or future regulation will not
adversely affect the operations of the Company. See "Business and
Properties -- Regulation."
DEPENDENCE ON KEY PERSONNEL
The success of the Company will be highly dependent on M. Jay Allison, its
President and Chief Executive Officer, and a limited number of other senior
management personnel. Loss of the services of Mr. Allison or any of those other
individuals could have a material adverse effect on the Company's operations.
See "Management."
NO DIVIDENDS
During the last five fiscal years, the Company has not paid any dividends
on its outstanding Common Stock, nor does the Company intend to do so. In
addition, the Company is restricted from doing so under the Bank Credit Facility
and by the terms of the Series 1995 Preferred. The Company currently intends to
retain its cash for the continued expansion of its business. See "Dividend
Policy."
10
<PAGE> 11
SHARES ELIGIBLE FOR FUTURE SALE
Sales of substantial amounts of Common Stock in the public market could
adversely affect the market price for the Common Stock. If the Company's
stockholders were to sell a significant number of shares, the prevailing market
price of the Common Stock could be adversely affected. The Company, its
executive officers and directors and the Selling Stockholders have agreed that,
without the consent of Smith Barney Inc., they will not sell any shares of
Common Stock for a period 120 days from the date of this Prospectus. See
"Principal and Selling Stockholders" and "Underwriting."
ANTI-TAKEOVER PROVISIONS
The Company's Articles of Incorporation, Bylaws and Stockholders' Rights
Plan and Nevada law include a number of provisions that may have the effect of
delaying or deterring a change in the control or management of the Company and
encouraging persons considering unsolicited tender offers or other unilateral
takeover proposals to negotiate with the Board of Directors rather than pursue
non-negotiated takeover attempts. See "Description of Capital Stock."
FORWARD-LOOKING INFORMATION
All statements other than statements of historical fact contained in this
Prospectus, including statements in "Management's Discussion and Analysis of
Financial Condition and Results of Operations" and "Business and Properties,"
are forward-looking statements. Forward-looking statements in this Prospectus
generally are accompanied by words such as "anticipate," "believe," "estimate,"
"expect," "intend," "plan," "project" or similar statements. Although the
Company believes that the expectations reflected in such forward-looking
statements are reasonable, no assurance can be given that such expectations will
prove correct. Factors that could cause the Company's results to differ
materially from the results discussed in such forward-looking statements include
the aforementioned risks described under "Risk Factors," such as the
fluctuations of the prices received or demand for the Company's oil and natural
gas, acquisition risks, requirements for capital, the ability to replace
depleting reserves, the uncertainty of drilling results and reserve estimates,
drilling risks, operating hazards, competition and the effects of governmental
and environmental regulation. All forward-looking statements in this Prospectus
are expressly qualified in their entirety by the cautionary statements in this
paragraph.
11
<PAGE> 12
USE OF PROCEEDS
The net proceeds to the Company from the Offering are estimated to be $47.0
million ($57.3 million if the Underwriters' over-allotment option is exercised
in full), at an offering price of $12.50. The Company will not receive any of
the proceeds from the sale of shares of Common Stock by the Selling
Stockholders. See "Principal and Selling Stockholders." The Company intends to
use all of the net proceeds to reduce outstanding indebtedness under the Bank
Credit Facility. At November 25, 1996, approximately $142.0 million in total
borrowings was outstanding under the Bank Credit Facility at an average interest
rate of 7.5% per annum. Outstanding borrowings under the Bank Credit Facility
were used to fund the Black Stone Acquisition and refinance existing
indebtedness. Available borrowing capacity under the Bank Credit Facility will
be used to fund future capital expenditures related to the Company's
acquisition, development, exploitation and exploration activities, and for
general corporate purposes. The Company currently has no agreements or
understandings in place with respect to any material acquisition.
DIVIDEND POLICY
The Company intends to retain any future earnings for use in its business
and does not intend to pay cash dividends on the Common Stock in the foreseeable
future. The payment of future dividends, if any, will be at the discretion of
the Company's Board of Directors and will depend upon, among other things,
future earnings, operations, capital requirements, restrictions in future
financing agreements, the general financial condition of the Company and general
business conditions. The payment of cash dividends on the Common Stock is
currently restricted under the Bank Credit Facility and by the terms of the
Series 1995 Preferred.
PRICE RANGE OF COMMON STOCK
The Common Stock is quoted on the Nasdaq National Market under the symbol
"CMRE." The table below sets forth the high and low reported sales prices of the
Common Stock on the Nasdaq National Market for the periods indicated.
<TABLE>
<CAPTION>
HIGH LOW
------ ------
<S> <C> <C>
1996
Fourth Quarter (through November 25, 1996)....................... $14.63 $11.13
Third Quarter.................................................... 12.13 8.63
Second Quarter................................................... 10.50 4.69
First Quarter.................................................... 5.75 4.56
1995
Fourth Quarter................................................... 5.63 4.00
Third Quarter.................................................... 4.88 3.75
Second Quarter................................................... 4.94 3.38
First Quarter.................................................... 3.69 2.75
1994
Fourth Quarter................................................... 3.63 2.81
Third Quarter.................................................... 4.56 3.00
Second Quarter................................................... 4.25 2.94
First Quarter.................................................... 5.75 3.00
</TABLE>
On November 25, 1996, the last reported sale price of the Common Stock on
the Nasdaq National Market was $12.875. As of October 23, 1996, there were
approximately 935 record holders of Common Stock.
12
<PAGE> 13
CAPITALIZATION
The following table sets forth the consolidated capitalization of the
Company as of September 30, 1996, and such capitalization as adjusted to reflect
(i) the issuance and sale by the Company of 4,000,000 shares of Common Stock in
the Offering and the application of the estimated net proceeds therefrom as
described under "Use of Proceeds" and (ii) the conversion of 793,677 shares of
Series 1995 Preferred into 1,511,761 shares of Common Stock as described under
"Pro Forma Financial Information." This information should be read in
conjunction with the Consolidated Financial Statements and the Pro Forma
Financial Statements, including the notes thereto, and "Management's Discussion
and Analysis of Financial Condition and Results of Operations" included
elsewhere in this Prospectus.
<TABLE>
<CAPTION>
AS OF SEPTEMBER 30, 1996
------------------------
PRO FORMA
ACTUAL AS ADJUSTED
-------- -----------
(IN THOUSANDS)
<S> <C> <C>
Total current debt.................................................. $ 171 $ 171
======== ========
Long-term debt:
Bank Credit Facility.............................................. $150,000 $ 103,000
Other............................................................. 9 9
-------- --------
Total long-term debt...................................... $150,009 $ 103,009
-------- --------
Stockholders' equity:
Preferred Stock -- $10.00 par, 5,000,000 shares authorized;
1,500,000 issued and outstanding; and 706,323 issued and
outstanding as adjusted(1)..................................... $ 15,000 $ 7,063
Common Stock -- $.50 par, 30,000,000 shares authorized; 17,340,742
issued and outstanding; and 22,852,506 issued and outstanding
as adjusted(1)................................................. 8,670 11,426
Additional paid-in capital........................................ 55,154 107,335
Accumulated deficit............................................... (29,832) (29,832)
Deferred compensation -- restricted stock grants.................. (42) (42)
-------- --------
Total stockholders' equity................................ 48,950 95,950
-------- --------
Total capitalization................................................ $198,959 $ 198,959
======== ========
</TABLE>
- ---------------
(1) Excludes, as of September 30, 1996, (i) 1,345,377 shares of Common Stock
reserved for issuance upon the conversion of outstanding shares of the
Series 1995 Preferred (after giving effect to the issuance of 1,511,761
shares of Common Stock upon conversion of preferred shares by certain
Selling Stockholders in connection with the Offering) and (ii) 2,937,680
shares of Common Stock reserved for issuance upon exercise of outstanding
stock options. Subsequent to such date, 339,127 shares of Common Stock have
been issued upon exercise of such options. See "Management -- Compensation
of Executive Officers," "Principal and Selling Stockholders," and
"Description of Capital Stock."
13
<PAGE> 14
PRO FORMA FINANCIAL INFORMATION
The accompanying Pro Forma Consolidated Statements of Operations for the
year ended December 31, 1995 and the nine months ended September 30, 1996 have
been prepared assuming the Company consummated, immediately prior to each of the
periods presented, (i) the 1995 Acquisitions, (ii) the 1996 Transactions and
(iii) the issuance and sale of shares of Common Stock in the Offering and the
application of the estimated net proceeds therefrom.
The pro forma financial information does not purport to present the actual
results of operations of the Company had the transactions and events assumed
therein in fact occurred at the dates specified, nor are they necessarily
indicative of the results of operations that may be achieved in the future. The
Pro Forma Consolidated Financial Statements are based on certain assumptions and
adjustments described in the notes thereto and should be read in conjunction
therewith and with "Management's Discussion and Analysis of Financial Condition
and Results of Operations" and the Consolidated Financial Statements and related
notes thereto included elsewhere in this Prospectus.
1995 ACQUISITIONS
The following acquisitions are collectively referred to as the "1995
Acquisitions":
SONAT ACQUISITION
In July 1995 the Company completed the acquisition of producing oil and
natural gas properties and natural gas gathering systems located in East Texas
and North Louisiana from Sonat Exploration Company, a wholly owned subsidiary of
Sonat Inc. ("Sonat"), for $50.6 million. The Company acquired interests in 319
producing wells (188.0 net) for $49.1 million and acquired the managing general
partner interest of and a 20.3% limited partner interest in Crosstex Pipeline
Partners, Ltd., as well as certain other natural gas gathering systems primarily
located in Harrison County, Texas, for $1.5 million.
OTHER 1995 ACQUISITIONS
In May 1995 the Company completed an acquisition of producing offshore oil
and natural gas properties located in Louisiana state waters in the Gulf of
Mexico. The Company acquired interests in 14 producing wells (3.5 net) for $8.2
million. During 1995 the Company also acquired interests in the Lake LaRose
field in South Louisiana for $1.0 million.
1996 TRANSACTIONS
The following transactions are collectively referred to as the "1996
Transactions":
BLACK STONE ACQUISITION
In May 1996 the Company acquired 100% of the capital stock of Black Stone
Oil Company and interests in producing and undeveloped oil and natural gas
properties located in the Double A Wells field in Southeast Texas for $104.0
million. The Company acquired interests in 19 producing wells (7.7 net).
1996 DISPOSITIONS
In May 1996 the Company sold certain oil and natural gas properties for
aggregate proceeds of $8.9 million. The properties sold include interests in 145
producing wells located in Oklahoma, Arkansas, Nebraska and Kansas, as well as
certain nonproducing acreage in South Texas (the "1996 Dispositions").
PREFERRED STOCK CONVERSIONS
On July 11, 1996, the Company redeemed all of the outstanding shares of its
1994 Series B Convertible Preferred Stock by issuing 2,000,000 shares of Common
Stock. The Company paid quarterly dividends on the 1994 Series B Convertible
Preferred Stock at an annual rate of 6.25% before the conversion (approximately
14
<PAGE> 15
$625,000 per year). On September 16, 1996, the holders of all of the outstanding
shares of the Company's Series 1994 Convertible Preferred Stock converted such
shares into 1,500,000 shares of Common Stock. The Company paid quarterly
dividends on the Series 1994 Convertible Preferred Stock at an annual rate of 9%
before the conversion (approximately $540,000 per year). In connection with the
Offering, the Company has been advised that the holders of the Series 1995
Preferred intend to convert 793,677 preferred shares into 1,511,761 shares of
Common Stock and sell such Common Stock in the Offering. The Company pays
quarterly dividends on the Series 1995 Preferred at an annual rate of 9%
(approximately $1,350,000 per year). As a result of the conversion of 793,677
shares of the Series 1995 Preferred, the Company's annual preferred dividend
obligation will be reduced by $714,000. See "Principal and Selling
Stockholders."
BANK CREDIT FACILITY
In August 1996 the Company entered into a $166.0 million revolving credit
agreement with The First National Bank of Chicago, as agent, and a syndicate of
ten additional banks (the "Bank Credit Facility"). Amounts outstanding under the
Bank Credit Facility bear interest at a floating rate based on the agent bank's
base rate plus 0.5% or, at the Company's option, at a fixed rate for up to six
months based LIBOR plus 1.25% to 2% depending upon the utilization of the
available borrowing base. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Liquidity and Capital Resources."
15
<PAGE> 16
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
PRO FORMA CONSOLIDATED STATEMENT OF OPERATIONS (UNAUDITED)
FOR THE YEAR ENDED DECEMBER 31, 1995
<TABLE>
<CAPTION>
PRO FORMA ADJUSTMENTS
---------------------------- PRO FORMA
BLACK STONE OTHER PRO FORMA OFFERING AS
HISTORICAL ACQUISITION TRANSACTIONS COMBINED ADJUSTMENTS ADJUSTED
---------- ----------- ------------ --------- ----------- ---------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C>
Revenues:
Oil and gas sales........... $ 22,091 $17,992(a) $ 8,042(b) $ 46,465 $ -- $ 46,465
(1,660)(c)
Gas marketing, gathering and
processing................ 50,678 -- 569(b) 51,247 -- 51,247
Other....................... 2,899 -- 71(b) 2,970 -- 2,970
-------- ------- ------- --------- ------- --------
Total revenues....... 75,668 17,992 7,022 100,682 -- 100,682
-------- ------- ------- --------- ------- --------
Expenses:
Oil and gas operating....... 7,427 2,453(a) 3,214(b) 12,078 -- 12,078
(1,016)(c)
Gas marketing, gathering and
processing................ 49,118 -- 518(b) 49,636 -- 49,636
Depreciation, depletion and
amortization.............. 8,613 7,244(d) 2,316(d) 17,500 -- 17,500
(673)(e)
General and administrative,
net....................... 1,979 (135)(f) 66(f) 1,910 -- 1,910
Interest.................... 5,542 7,717(g) 2,382(g) 13,400 (3,275)(j) 10,125
(666)(h)
(1,575)(i)
Impairment of oil and gas
properties................ 29,150 -- -- 29,150 -- 29,150
-------- ------- ------- --------- ------- --------
Total expenses....... 101,829 17,279 4,566 123,674 (3,275) 120,399
-------- ------- ------- --------- ------- --------
Income (loss) before income
taxes....................... (26,161) 713 2,456 (22,992) 3,275 (19,717)
Provision for income taxes.... -- -- -- -- -- --
-------- ------- ------- --------- ------- --------
Net income (loss)............. (26,161) 713 2,456 (22,992) 3,275 (19,717)
Preferred stock dividends..... (1,908) -- 1,173(k) (735) 389(k) (346)
-------- ------- ------- --------- ------- --------
Net income (loss) attributable
to common stock............. $(28,069) $ 713 $ 3,629 $ (23,727) $ 3,664 $(20,063)
======== ======= ======= ========= ======= ========
Net income (loss) per share... $ (2.24) $ (.96)
======== ========
Weighted average common
shares outstanding........ 12,546 20,870
======== ========
</TABLE>
See Notes to Pro Forma Consolidated Financial Statements.
16
<PAGE> 17
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
PRO FORMA CONSOLIDATED STATEMENT OF OPERATIONS (UNAUDITED)
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1996
<TABLE>
<CAPTION>
PRO FORMA ADJUSTMENTS
---------------------------- PRO FORMA
BLACK STONE OTHER PRO FORMA OFFERING AS
HISTORICAL ACQUISITION TRANSACTIONS COMBINED ADJUSTMENTS ADJUSTED
---------- ----------- ------------ --------- ----------- ---------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C>
Revenues:
Oil and gas sales...................... $ 45,517 $11,087(a) $ (605)(c) $ 55,999 $ -- $ 55,999
Gas marketing, gathering and
processing........................... 68,114 -- -- 68,114 -- 68,114
Other.................................. 1,961 -- -- 1,961 -- 1,961
-------- ------- ------- -------- ------- --------
Total revenues.................. 115,592 11,087 (605) 126,074 -- 126,074
-------- ------- ------- -------- ------- --------
Expenses:
Oil and gas operating.................. 9,673 1,147(a) (313)(c) 10,507 -- 10,507
Gas marketing, gathering and
processing........................... 66,301 -- -- 66,301 -- 66,301
Exploration............................ 285 -- -- 285 -- 285
Depreciation, depletion and
amortization......................... 12,809 3,411(d) (138)(e) 16,082 -- 16,082
General and administrative, net........ 1,546 (58)(f) 217(f) 1,705 -- 1,705
Interest............................... 7,619 2,393(g) (206)(h) 8,581 (2,273)(j) 6,308
(1,225)(i)
-------- ------- ------- -------- ------- --------
Total expenses.................. 98,233 6,893 (1,665) 103,461 (2,273) 101,188
-------- ------- ------- -------- ------- --------
Income before income taxes............... 17,359 4,194 1,060 22,613 2,273 24,886
Provision for income taxes............... -- -- -- -- -- --
-------- ------- ------- -------- ------- --------
Net income............................... 17,359 4,194 1,060 22,613 2,273 24,886
Preferred stock dividends................ (1,747) -- 720(k) (1,027) 544(k) (483)
-------- ------- ------- -------- ------- --------
Net income attributable to common
stock.................................. $ 15,612 $ 4,194 $ 1,780 $ 21,586 $ 2,817 $ 24,403
======== ======= ======= ======== ======= ========
Net income per share:
Primary................................ $ 1.04 $ 1.02
======== ========
Fully diluted.......................... $ 0.82 $ 0.99
======== ========
Weighted average common shares
outstanding:
Primary................................ 15,014 24,025
======== ========
Fully diluted.......................... 21,246 25,246
======== ========
</TABLE>
See Notes to Pro Forma Consolidated Financial Statements.
17
<PAGE> 18
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO PRO FORMA CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
The pro forma adjustments to the Consolidated Statements of Operations for
the year ended December 31, 1995, and the nine months ended September 30, 1996
are summarized below:
(a) To record revenues and direct operating expenses of the Black Stone
Acquisition from January 1, 1996 to May 1, 1996, the closing date of
the acquisition.
(b) To record the inclusion of revenues and direct operating expenses of
the 1995 Acquisitions from January 1, 1995 to the date of each
respective acquisition.
(c) To record the exclusion of revenues and direct operating expenses of
the properties that are the subject of the 1996 Dispositions.
(d) To record estimated depreciation, depletion and amortization
attributable to the Black Stone Acquisition and the 1995 Acquisitions
using the unit-of-production method applied to the net cost of the
properties acquired.
(e) To exclude depreciation, depletion and amortization attributable to the
properties that are the subject of the 1996 Dispositions.
(f) To record the estimated impact on general and administrative expense
net of the operating fee income that would have been received with
respect to the Black Stone Acquisition and the 1995 Acquisitions and to
eliminate operating fee income that was attributable to the 1996
Dispositions.
(g) To record interest expense attributable to the increase in debt to
finance the Black Stone Acquisition and the 1995 Acquisitions. Interest
expense is based upon the average interest rate of 7.5% for the year
ended December 31, 1995 and 7.0% for the nine months ended September
30, 1996 that would have been incurred by the Company under the Bank
Credit Facility assuming the entire cost of the acquisitions had been
funded with bank borrowings at January 1 of each period.
(h) To record the decrease in interest expense attributable to the
application of proceeds from the 1996 Dispositions against long-term
debt at the beginning of the applicable period.
(i) To reduce interest expense to reflect the effect of the Bank Credit
Facility assuming the Bank Credit Facility had been in place for the
entire period.
(j) To eliminate interest expense incurred under the Bank Credit Facility
assuming the proceeds of the Offering were used to reduce debt as of
January 1 of each period.
(k) To eliminate the dividends paid on the Company's Series 1994
Convertible Preferred Stock, 1994 Series B Convertible Preferred Stock
and a portion of the Series 1995 Preferred, assuming the conversion of
the preferred stock occurred as of January 1 of each period.
No adjustment has been made to reflect income taxes related to the 1995
Acquisitions or the 1996 Transactions due to the Company's net operating loss
carryforwards which would offset any current or deferred tax liabilities.
18
<PAGE> 19
SELECTED HISTORICAL FINANCIAL DATA
The historical financial data presented in the table below as of and for
each of the years in the five-year period ended December 31, 1995 and as of and
for the nine months ended September 30, 1995 and 1996 are derived from the
Consolidated Financial Statements of the Company. The historical consolidated
financial data as of and for the nine months ended September 30, 1995 and 1996
are derived from unaudited consolidated financial statements of the Company
which, in the opinion of management, contain all adjustments (consisting of
normal recurring adjustments) necessary for fair presentation. The results for
the nine months ended September 30, 1996 are not necessarily indicative of the
results that may be achieved for the full year. The data presented below should
be read in conjunction with the Company's Consolidated Financial Statements and
the notes thereto included elsewhere herein and "Management's Discussion and
Analysis of Financial Condition and Results of Operations."
<TABLE>
<CAPTION>
NINE MONTHS
YEAR ENDED DECEMBER 31, ENDED SEPTEMBER 30,
---------------------------------------------------- -------------------
1991 1992 1993 1994 1995 1995 1996
-------- -------- -------- -------- -------- -------- --------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA(1):
Revenues:
Oil and gas sales........................... $ 2,710 $ 10,680 $ 21,805 $ 16,855 $ 22,091 $ 14,254 $ 45,517
Gas marketing sales......................... -- -- -- 14,957 50,078 34,786 67,574
Gas gathering and processing................ 153 213 107 72 600 454 540
Gain on sales of property................... 106 -- 111 328 2,608 2,608 1,506
Other income................................ 160 220 430 442 291 206 455
-------- -------- -------- -------- -------- -------- --------
Total revenues............................ 3,129 11,113 22,453 32,654 75,668 52,308 115,592
-------- -------- -------- -------- -------- -------- --------
Expenses:
Oil and gas operating(2).................... 1,572 3,150 6,673 6,099 7,427 4,803 9,673
Natural gas purchases....................... -- -- -- 14,521 48,909 33,974 66,104
Gas gathering and processing................ 120 159 91 11 209 135 197
Exploration................................. -- -- 423 -- -- -- 285
Depreciation, depletion and amortization.... 1,758 3,759 8,334 7,390 8,613 6,114 12,809
General and administrative, net............. 2,089 1,485 1,834 1,823 1,979 1,448 1,546
Interest.................................... 449 1,037 2,184 2,869 5,542 3,574 7,619
Impairment of oil and gas properties(3)..... -- -- -- -- 29,150 -- --
Other....................................... 701 -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- --------
Total expenses............................ 6,689 9,590 19,539 32,713 101,829 50,048 98,233
-------- -------- -------- -------- -------- -------- --------
Income (loss) before income taxes............. (3,560) 1,523 2,914 (59) (26,161) 2,260 17,359
Provision for income taxes.................... -- -- -- -- -- -- --
-------- -------- -------- -------- -------- -------- --------
Net income (loss) before extraordinary
items....................................... (3,560) 1,523 2,914 (59) (26,161) 2,260 17,359
Preferred stock dividends..................... -- (56) (173) (818) (1,908) (1,267) (1,747)
-------- -------- -------- -------- -------- -------- --------
Net income (loss) attributable to common
stock....................................... (3,560) 1,467 2,741 (877) (28,069) 993 15,612
Extraordinary loss............................ -- -- (417) (615) -- -- --
-------- -------- -------- -------- -------- -------- --------
Net income (loss)............................. $ (3,560) $ 1,467 $ 2,324 $ (1,492) $(28,069) $ 993 $ 15,612
======== ======== ======== ======== ======== ======== ========
Weighted average common shares outstanding:
Primary..................................... 7,006 8,180 10,762 12,065 12,546 12,843 15,014
Fully diluted............................... 21,246
Primary earnings per share:
Net income (loss) before extraordinary
items..................................... $ (0.51) $ 0.18 $ 0.25 $ (0.07) $ (2.24) $ 0.08 $ 1.04
Net income (loss) after extraordinary
items..................................... (0.51) 0.18 0.22 (0.12) (2.24) 0.08 1.04
Fully diluted earnings per share.............. 0.82
CASH FLOW DATA:
Cash provided (used) by:
Operating activities........................ $ (583) $ (1,020) $ 16,488 $ 7,376 $ 8,407 $ 2,996 $ 27,275
Investing activities........................ (18,110) (12,472) (17,415) (23,972) (58,724) (56,713) (97,720)
Financing activities........................ 19,809 12,910 790 19,266 48,809 51,261 79,647
OTHER FINANCIAL DATA:
EBITDA(4)..................................... $ (1,353) $ 6,319 $ 13,855 $ 10,200 $ 17,144 $ 11,948 $ 38,072
Capital expenditures.......................... 19,962 12,457 21,779 16,386 61,809 59,708 106,668
</TABLE>
<TABLE>
<CAPTION>
AS OF SEPTEMBER 30,
AS OF DECEMBER 31,
---------------------------------------------------- -------------------
1991 1992 1993 1994 1995 1995 1996
-------- -------- -------- -------- -------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C> <C>
BALANCE SHEET DATA:
Property and equipment, net................... $ 44,784 $ 53,474 $ 66,068 $ 77,989 $102,116 $131,708 $188,233
Total assets.................................. 51,944 66,185 74,095 91,571 120,099 144,400 222,383
Total debt.................................... 7,843 19,164 21,930 37,932 71,811 74,258 150,180
Stockholders' equity.......................... 18,850 23,110 27,646 41,205 30,128 58,544 48,950
</TABLE>
- ---------------
(1) Significant acquisitions of producing oil and gas properties affect the
comparability of the historical financial and operating data for the periods
presented.
(2) Includes lease operating costs and production and ad valorem taxes.
(3) Represents the impairment provision for the adoption of a new accounting
standard regarding the carrying value of long-lived assets.
(4) As used in this Prospectus, EBITDA means income (loss) before income taxes,
plus interest, depreciation, depletion and amortization, impairment of oil
and gas properties and exploration.
19
<PAGE> 20
MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
RESULTS OF OPERATIONS
GENERAL
The Company's results of operations have been significantly affected by its
success in acquiring producing oil and natural gas properties. Fluctuations in
oil and natural gas prices have also influenced the Company's financial results.
Relatively minor movements in natural gas prices can lead to a change in the
Company's results of operations and cash flow and could have an impact on the
Company's borrowing base under the Bank Credit Facility. Based on the operating
results for the nine months ended September 30, 1996, a change in the average
natural gas price realized by the Company of $0.10 per Mcf would result in a
change in net income attributable to Common Stock of approximately $1.4 million,
or $0.06 per share. See "Risk Factors -- Market Conditions and Volatility of Oil
and Natural Gas Prices."
The following table reflects certain summary operating data for the periods
presented:
<TABLE>
<CAPTION>
NINE MONTHS
ENDED SEPTEMBER
YEAR ENDED DECEMBER 31, 30,
-------------------------- -----------------
1993 1994 1995 1995 1996
------ ------ ------ ------ -------
<S> <C> <C> <C> <C> <C>
NET PRODUCTION DATA:
Oil (MBbls)............................ 278 263 356 236 650
Natural gas (MMcf)..................... 8,514 6,514 9,297 6,198 13,651
AVERAGE SALES PRICE:
Oil (per Bbl).......................... $16.22 $15.22 $16.81 $16.78 $ 20.73
Natural gas (per Mcf).................. 2.03 1.97 1.73 1.66 2.35
EXPENSES ($ PER MCFE):
Oil and gas operating(1)............... $ 0.66 $ 0.75 $ 0.65 $ 0.63 $ 0.55
General and administrative, net........ 0.18 0.23 0.17 0.19 0.09
Depreciation, depletion and
amortization(2)..................... 0.78 0.88 0.72 0.77 0.71
</TABLE>
- ---------------
(1) Includes lease operating costs and production and ad valorem taxes.
(2) Represents depreciation, depletion and amortization of oil and gas
properties only.
Average oil and natural gas prices received by the Company generally
fluctuate with changes in the posted prices for oil and spot market prices for
natural gas. The Company enters into natural gas price swap agreements to reduce
its exposure to natural gas price fluctuations. In 1995 the Company hedged
approximately 25% of its natural gas production and realized 6% higher average
gas prices than it otherwise would have without hedging. For the nine months
ended September 30, 1996, the Company hedged approximately 13% of its natural
gas production and realized a 1% lower gas price than it otherwise would have
without hedging.
The Company has entered into natural gas price swap agreements to hedge
approximately 0.9 Bcf of its natural gas production for the fourth quarter of
1996 at an average price of $1.90 per MMBtu. The swap agreements include
estimated delivery point basis adjustments to better equate the agreements to
the Company's expected well head prices to be received. The Company has no
hedges in place for 1997 or subsequent years.
The Company is currently evaluating a potential sale of its gas gathering
and processing assets and third party gas marketing operations. Management
believes that any such transaction would not have a material impact on the
Company's results of operations or financial position.
20
<PAGE> 21
ADOPTION OF NEW ACCOUNTING STANDARD
Prior to the fourth quarter of 1995, the Company periodically reviewed the
carrying value of its proved oil and gas properties for impairment in value on a
company-wide basis by comparing the capitalized costs of proved oil and gas
properties with the undiscounted future cash flows after income taxes
attributable to such properties. Under this policy, no impairment in carrying
value was required during 1993 or 1994. In the fourth quarter of 1995, the
Company adopted the Statement of Financial Accounting Standards No. 121
"Accounting for the Impairment of Long-Lived Assets and Long-Lived Assets to be
Disposed of" ("SFAS 121"). SFAS 121 requires the Company to assess the need for
an impairment of capitalized costs of oil and gas properties on a
property-by-property basis. If an impairment is indicated based on undiscounted
expected future cash flows, then an impairment is recognized to the extent that
net capitalized costs exceed discounted expected future cash flows. In
connection with the adoption of SFAS 121, the Company provided an impairment of
approximately $29.2 million in 1995. Of the total impairment provision, $20.0
million relates to a writedown of the carrying value of the Company's
undeveloped acreage in the Texas Panhandle field acquired from 1988 to 1990.
NINE MONTHS ENDED SEPTEMBER 30, 1996 COMPARED TO NINE MONTHS ENDED SEPTEMBER
30, 1995
Oil and gas sales increased $31.3 million (219%), to $45.5 million for the
first nine months of 1996 from $14.3 million in the first nine months of 1995
due primarily to a 120% increase in natural gas production and a 175% increase
in oil production as well as higher oil and natural gas prices. The production
increases related primarily to production from properties acquired in the 1995
Acquisitions and the Black Stone Acquisition, which closed in May 1996. The
Company's average gas price increased 42% and its average oil price increased
24% during the first nine months of 1996 compared to the same period in 1995.
Gas marketing net margins (revenues less expenses) increased $658,000 (81%)
to $1.5 million in 1996 from $812,000 in 1995 due primarily to an increase in
volumes marketed and higher natural gas prices realized.
Gas gathering and processing net margins (revenues less expenses) increased
$24,000 (8%) to $344,000 in the first nine months of 1996 from $319,000 in the
same period of 1995.
Other income increased $249,000 (121%) to $455,000 in the first nine months
of 1996 from $206,000 in first nine months of 1995 due primarily to interest
income earned on short-term cash deposits in 1996.
Oil and gas operating expenses, including production taxes, increased $4.9
million (101%) to $9.7 million in the first nine months of 1996 from $4.8
million in the first nine months of 1995 due primarily to the 130% increase in
oil and gas production (on an Mcfe basis) resulting primarily from the 1995
Acquisitions and the Black Stone Acquisition. Oil and gas operating expenses per
Mcfe produced decreased 13% to $0.55 in 1996 from $0.63 in 1995 due to the lower
lifting costs associated with the properties acquired in 1995 and 1996.
General and administrative expenses increased $98,000 (7%) to $1.5 million
in the first nine months of 1996 from $1.4 million in the first nine months of
1995 due primarily to an increase in the number of employees of the Company.
Depreciation, depletion and amortization ("DD&A") increased $6.7 million
(110%) to $12.8 million in the first nine months of 1996 from $6.1 million in
the first nine months of 1995 due primarily to the increase in oil and natural
gas production. Oil and gas property DD&A per Mcfe produced decreased by 8% to
$0.71 in 1996 from $0.77 in 1995 due to the lower acquisition costs associated
with the properties acquired in 1995.
Interest expense increased $4.0 million (113%) to $7.6 million for the
first nine months of 1996 from $3.6 million for the first nine months of 1995
due primarily to an increase in the average outstanding advances under the
Company's previous bank credit facility. The average annual interest rate paid
under the Company's previous bank credit facility decreased to 8.3% in the first
nine months of 1996 as compared to 10.5% in the first nine months of 1995.
21
<PAGE> 22
The Company reported net income of $17.4 million before preferred stock
dividends of $1.7 million for the nine months ended September 30, 1996, as
compared to net income of $2.3 million before preferred stock dividends of $1.3
million for the first nine months ended September 30, 1995.
YEAR ENDED DECEMBER 31, 1995 COMPARED TO YEAR ENDED DECEMBER 31, 1994
Oil and gas sales increased $5.2 million (31%) to $22.1 million in 1995
from $16.9 million in 1994 due primarily to a 43% increase in natural gas
production and a 35% increase in oil production. The production increases
related primarily to production from certain oil and natural gas property
acquisitions completed in late 1994 and in 1995. The production increases were
partially offset by a 12% decrease in the Company's average gas price. The
Company's average oil price for the period increased by 10%.
Gas marketing net margins (revenues less expenses) increased $733,000
(168%) to $1.2 million in 1995 from $437,000 in 1994 due primarily to a full
year of natural gas marketing operations in 1995 as compared to only seven
months of operations in 1994. The average margin per Mcf sold was $0.032 in 1995
as compared to $0.041 in 1994.
Gas gathering and processing net margins (revenues less expenses) increased
$329,000 (536%) to $390,000 in 1995 from $61,000 in 1994 due primarily to
acquisitions of certain gathering and processing assets in late 1994 and in
1995.
Oil and gas operating expenses, including production taxes, increased $1.3
million (22%) to $7.4 million in 1995 from $6.1 million in 1994 due primarily to
the 41% increase in oil and natural gas production (on an Mcfe basis) resulting
from the property acquisitions previously discussed. Lease operating expenses
per Mcfe produced decreased 15% to $0.65 in 1995 from $0.75 in 1994 due to the
lower lifting costs associated with the properties acquired in 1995.
General and administrative expenses increased $156,000 (9%) to $2.0 million
in 1995 from $1.8 million in 1994 due primarily to the addition of personnel
associated with the Company's commencement of gas marketing operations in June
1994.
DD&A increased $1.2 million (17%) to $8.6 million in 1995 from $7.4 million
in 1994 due primarily to the 41% increase in oil and natural gas production (on
an Mcfe basis). Oil and gas property DD&A per Mcfe produced decreased 18% to
$0.72 in 1995 from $0.88 in 1994.
Interest expense increased $2.7 million (93%) to $5.5 million in 1995 from
$2.8 million in 1994 due primarily to an increase in the average outstanding
advances under the Company's previous bank credit facility and an increase in
interest rates. The average annual interest rate paid under the Company's
previous bank credit facility was 10.5% in 1995 as compared to 8.6% in 1994.
The Company reported a loss of $26.2 million before preferred stock
dividends of $1.9 million for the year ended December 31, 1995 as compared to a
loss of $59,000 before preferred stock dividends of $818,000 for the year ended
December 31, 1994. The loss in 1995 is attributable to the Company's adoption of
SFAS 121 which resulted in the Company recording an impairment of its oil and
gas properties of $29.2 million relating to the adoption of SFAS 121. The 1995
results also include a $2.6 million gain from the sale in 1995 of a gas
processing plant for $3.0 million.
YEAR ENDED DECEMBER 31, 1994 COMPARED TO YEAR ENDED DECEMBER 31, 1993
Oil and gas sales decreased $4.9 million (23%), to $16.9 million in 1994
from $21.8 million in 1993 due primarily to a 23% decrease in natural gas
production. Oil production increased 6% in 1994. Sales were also impacted by a
3% decrease in gas prices and a 6% decrease in oil prices. The natural gas
production decline related primarily to the decrease in the ownership interest
in the West Cameron property to 45% from 90% resulting from the effect of a
reversionary interest.
Gas marketing net margins (revenues less expenses) reported in 1994 were
$437,000 as a result of the commencement of gas marketing operations by the
Company in June 1994. The average margin per Mcf sold was $0.041 in 1994.
22
<PAGE> 23
Gas gathering net margin (revenues less expenses) was $61,000 in 1994 which
relates to certain gas gathering assets acquired in September 1994. The gas
gathering net margin of $17,000 in 1993 related to a gas gathering system in
Oklahoma which the Company sold in 1993.
Oil and gas operating expenses, including production taxes, decreased
$575,000 (9%) to $6.1 million in 1994 from $6.7 million in 1993 due primarily to
the 21% decrease in oil and gas production on an Mcfe basis as discussed above.
Lease operating expenses per equivalent Mcf produced increased 14% to $0.75 in
1994 from $0.66 in 1993.
General and administrative expenses of $1.8 million in 1994 were comparable
to general and administrative expenses in 1993.
DD&A decreased $900,000 (11%) to $7.4 million in 1994 from $8.3 million
1993 due primarily to the 21% decrease in oil and natural gas production on an
Mcfe basis. Oil and gas property DD&A per Mcfe produced increased 13% to $0.88
in 1994 as compared to $0.78 in 1993.
Interest expense increased $686,000 (31%) to $2.9 million in 1994 from $2.2
million in 1993 due primarily to an increase in the average outstanding advances
under the Company's bank credit facility partially offset by lower average
interest rates in 1994.
The Company reported a loss of $59,000 before preferred stock dividends of
$818,000 for the year ended December 31, 1994, as compared to income of $2.9
million before preferred stock dividends of $173,000 in 1993. The aforementioned
decrease in the Company's oil and natural gas production of 21% (on an Mcfe
basis) accounted for the decline in earnings.
LIQUIDITY AND CAPITAL RESOURCES
Funding for the Company's activities has historically been provided by
operating cash flows, debt and equity financings and asset dispositions. Net
cash flows provided by operating activities totaled $8.4 million for the year
ended December 31, 1995 and $27.3 million for the nine months ended September
30, 1996.
The Company's primary needs for capital, in addition to funding of ongoing
operations, are for the acquisition, development and exploration of oil and gas
properties, and the repayment of principal and interest on indebtedness.
The Company's annual capital expenditure activity is summarized as follows:
<TABLE>
<CAPTION>
NINE MONTHS
YEAR ENDED DECEMBER 31, ENDED SEPTEMBER 30,
----------------------------- -------------------
1993 1994 1995 1995 1996
------- ------- ------- ------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C>
Acquisition of oil and gas
reserves.......................... $18,500 $12,970 $56,081 $55,659 $100,075
Other leasehold costs............... 350 607 12 -- 71
Workovers and recompletions......... 1,066 1,271 2,152 1,283 2,356
Development drilling................ 1,324 218 1,514 852 3,678
Exploratory drilling................ 423 -- -- -- 285
Acquisition of gas marketing,
processing and gathering assets... -- 1,099 2,009 1,875 128
Other............................... 116 221 41 39 75
------- ------- ------- ------- --------
Total..................... $21,779 $16,386 $61,809 $59,708 $106,668
======= ======= ======= ======= ========
</TABLE>
The timing of most of the Company's capital expenditures is discretionary
with no material long-term capital expenditure commitments. Consequently, the
Company has a significant degree of flexibility to adjust the level of such
expenditures as circumstances warrant. During 1995 and the first nine months of
1996, the Company spent $3.7 million and $6.3 million, respectively, on
development and exploration activities. As part of its increased emphasis on
such activities, the Company currently anticipates spending in excess of $20.0
million on identified development and exploration projects in the fourth quarter
of 1996 through 1997.
23
<PAGE> 24
The increase in capital expenditures for 1996 over prior year levels is
primarily attributable to the increased opportunities available to the Company
after recent acquisitions. The Company does not have a specific acquisition
budget as a result of the unpredictability of the timing and size of forthcoming
acquisition activities.
The Company intends to primarily use internally generated cash flow to fund
capital expenditures other than significant acquisitions. The Company
anticipates that such sources will be sufficient to fund the balance of the
Company's 1996 capital expenditure budget and expected 1997 capital
expenditures. The Company primarily intends to use borrowings under the Bank
Credit Facility to finance possible significant acquisitions. In addition, the
Company may seek to obtain other debt or equity financing. The availability and
attractiveness of these sources of financing will depend upon a number of
factors, some of which will relate to the financial condition and performance of
the Company, and some of which will be beyond the Company's control, such as
prevailing interest rates, oil and natural gas prices and other market
conditions. In addition, the ability of the Company to incur additional
indebtedness and grant security interests with respect thereto will be limited
by the terms of the Bank Credit Facility.
The Company's bank credit facility consists of a $166.0 million revolving
credit commitment provided by a syndicate of 11 banks in which The First
National Bank of Chicago serves as agent. All indebtedness under the Bank Credit
Facility is secured by substantially all of the Company's assets. The Bank
Credit Facility is subject to borrowing base availability as determined from
time to time by the lenders, in the exercise of their sole discretion. As of
September 30, 1996, the borrowing base was $166.0 million. Such borrowing base
may be affected from time to time by the performance of the Company's oil and
natural gas properties and changes in oil and natural gas prices. The revolving
credit line bears interest at the option of the Company at either (i) LIBOR plus
1.25% to 2% or (ii) the higher of the "corporate base rate" plus 0% to 0.5% or
0.5% over the federal funds rate plus 0% to 0.5%. The average annual interest
rate as of September 30, 1996, of all outstanding indebtedness under the Bank
Credit Facility was approximately 7.6%. The Company incurs a commitment fee of
up to 0.5% per annum on the unused portion of the borrowing base. The revolving
credit line will convert to a term loan (the "Term Loan") on August 13, 1999 or
such earlier date as the Company may elect. The Term Loan is to be repaid in
consecutive quarterly installments of 5% of the original outstanding principal
amount of the Term Loan; the balance of the Term Loan will be due and payable in
full on August 13, 2001. The Bank Credit Facility contains covenants which,
among other things, restrict the payment of cash dividends, limit the amount of
consolidated debt, and limit the Company's ability to make certain loans and
investments.
FEDERAL TAXATION
At December 31, 1995, the Company had federal income tax net operating loss
("NOL") carryforwards of approximately $31.0 million. The NOL carryforwards
expire from 1996 through 2010. The value of these carryforwards depends on the
ability of the Company to generate federal taxable income and to utilize the
carryforwards to reduce such income. The Internal Revenue Code of 1986, as
amended (the "Code") limits the utilization of NOL carryforwards under certain
circumstances, including upon the occurrence of certain ownership changes. The
Company believes that an ownership change may occur during 1996 as a result of
this Offering and/or other transactions involving the Company's capital stock.
Based on recent trading prices for the Common Stock, the Company does not
believe that any limitation caused by an ownership change will have a
significant effect on its ability to use its NOL carryforwards to offset future
federal taxable income, although there can be no assurance this will be the
case.
The Company does not expect to report any regular taxable income in the
near future because it expects to utilize its carryforwards and other tax
deductions and credits. However, there is no assurance that the Internal Revenue
Service will not challenge these carryforwards or their utilization.
INFLATION
In recent years inflation has not had a significant impact on the Company's
operations or financial condition.
24
<PAGE> 25
BUSINESS AND PROPERTIES
GENERAL
Comstock Resources, Inc. is an independent energy company engaged in the
acquisition, development, production and exploration of oil and natural gas
properties. The Company is also engaged in the gathering, processing and
marketing of natural gas. As of December 31, 1995, the Company had pro forma
proved reserves of 307.9 Bcfe with an estimated Present Value of Proved Reserves
of $286.4 million. On a Bcfe basis, these reserves were 83% natural gas and 74%
proved developed. The Company believes that its primary strengths include (i)
its ability to acquire oil and natural gas properties at attractive costs, (ii)
its high quality, long-lived reserve base, of which 92% is concentrated in
Southeast Texas, East Texas/North Louisiana and the Texas Gulf Coast, and (iii)
its ability to efficiently operate and develop its oil and natural gas
properties.
The Company has grown primarily through the acquisition of producing
properties. Since 1991 the Company has added 286.8 Bcf of natural gas and 10.5
MMBbls of oil from 16 acquisitions at a total cost of $225.5 million, or $0.64
per Mcfe. The Company's two largest acquisitions to date have been its purchase
of properties from Sonat Inc. in July 1995 for $50.6 million (the "Sonat
Acquisition") and its acquisition of Black Stone Oil Company and interests in
the Double A Wells field in May 1996 for $104.0 million (the "Black Stone
Acquisition"). Primarily as a result of the Company's acquisition activities,
(i) average net daily production increased from 27.9 MMcfe in 1993 to 78.9 MMcfe
on a pro forma basis for the nine months ended September 30, 1996 and (ii)
EBITDA (as defined) increased from $13.9 million for 1993 to $37.1 million on a
pro forma basis for 1995. EBITDA on a pro forma basis for the first nine months
of 1996 was $47.6 million.
While continuing to pursue attractive acquisitions, the Company has
recently increased its focus on the exploitation and development of its existing
properties through the implementation of operational improvements, workovers,
recompletions and the drilling of development and exploratory wells. During 1995
and the first nine months of 1996, the Company spent $3.7 million and $6.3
million, respectively, on development and exploration activities. As part of its
increased emphasis on such activities, the Company anticipates spending in
excess of $20.0 million on currently identified development and exploration
projects in the fourth quarter of 1996 through 1997.
BUSINESS STRATEGY
The Company's strategy is to increase cash flow and net asset value by
acquiring oil and natural gas properties at attractive costs and developing its
reserves. In addition, the Company intends to pursue selective exploration
opportunities in its core operating areas. The key elements of the Company's
business strategy are to:
ACQUIRE HIGH QUALITY PROPERTIES AT ATTRACTIVE COSTS
The Company has a successful track record of increasing its reserves
through opportunistic acquisitions. The Company applies strict economic and
reserve risk criteria in evaluating acquisitions and targets properties with
established production where it can obtain operational control and increase
production and reserves through exploitation activities. The Black Stone
Acquisition and the Sonat Acquisition have significant development and
exploration potential and were acquired at costs equal to 70% and 68%,
respectively, of their estimated Present Value of Proved Reserves. Due to its
experience in its core operating areas, the Company believes it is better able
to identify and evaluate potential acquisitions and negotiate and close selected
acquisitions on favorable terms.
OPERATE PROPERTIES
The Company prefers to operate the properties it acquires, allowing it to
exercise greater control over the timing and plans for future development, the
level of drilling and lifting costs, and the marketing of production. The
Company operates properties comprising approximately 85% of its pro forma
Present Value of Proved Reserves as of December 31, 1995.
25
<PAGE> 26
MAINTAIN LOW COST STRUCTURE
The Company seeks to increase cash flow by carefully controlling operating
costs and general and administrative expense. The Company targets acquisitions
that possess, among other characteristics, low per unit operating costs. In
addition, the Company has been able to reduce per unit operating costs by
eliminating unnecessary field and corporate overhead costs and by divesting
properties that have high lifting costs with little future development
potential. Through these efforts, the Company's general and administrative
expense and average oil and gas operating costs per Mcfe have decreased from
$0.18 and $0.66, respectively, for 1993 to $0.08 and $0.49, respectively, on a
pro forma basis for the nine months ended September 30, 1996.
EXPLOIT EXISTING RESERVES
The Company seeks to maximize the value of its properties by increasing
production and recoverable reserves through active workover, recompletion and
exploitation activities. The Company utilizes advanced industry technology,
including 3-D seismic data, magnetic resonance imaging logging tools and newly
developed formation stimulation techniques. During the first nine months of
1996, the Company participated in the drilling of 14 development wells, and
plans to participate in 14 additional development wells during the fourth
quarter. The Company has identified 23 development wells to be drilled in 1997
and expects to drill additional wells based on drilling results and geologic
work in progress.
PURSUE SELECTIVE EXPLORATION OPPORTUNITIES
The Company pursues selective exploration activities to find additional
reserves on its undeveloped acreage and anticipates spending approximately 15%
of its 1997 drilling budget on exploration. The Company recently completed a 3-D
seismic survey in the East White Point field along the Texas Gulf Coast and
plans to drill an exploratory well in this field in the fourth quarter of 1996
and a deeper exploratory test well in the first quarter of 1997. In the West
Simsboro field in North Louisiana, the Company has completed a geological field
study and intends to drill an exploratory well to test an undeveloped fault
block by the end of 1996. The Company is also participating in the exploration
of undeveloped acreage adjacent to the Double A Wells field in Southeast Texas.
In 1997 the Company intends to participate in 3-D seismic surveys on its
offshore leases in the Gulf of Mexico.
The Company's executive offices are located at 5005 LBJ Freeway, Suite
1000, Dallas, Texas 75244, and its telephone number is (972) 701-2000.
OIL AND NATURAL GAS RESERVES
The following tables set forth the estimated oil and natural gas proved
reserves of the Company and the Present Value of Proved Reserves as of December
31, 1995 (both historical and on a pro forma basis for the Black Stone
Acquisition and the 1996 Dispositions):
HISTORICAL
<TABLE>
<CAPTION>
NET PROVED RESERVES PRESENT
------------------------------- VALUE OF
OIL GAS TOTAL PROVED
CATEGORY (MBBLS) (MMCF) (MMCFE) RESERVES
-------- ------- ------- ------- --------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Proved developed producing...................... 1,937 79,473 91,097 $ 88,404
Proved developed non-producing.................. 625 50,902 54,654 31,278
Proved undeveloped.............................. 1,217 42,790 50,089 28,610
----- ------- ------- --------
Total proved.......................... 3,779 173,165 195,840 $148,292
===== ======= ======= ========
</TABLE>
26
<PAGE> 27
PRO FORMA FOR THE BLACK STONE ACQUISITION AND 1996 DISPOSITIONS
<TABLE>
<CAPTION>
NET PROVED RESERVES PRESENT
------------------------------- VALUE OF
OIL GAS TOTAL PROVED
CATEGORY (MBBLS) (MMCF) (MMCFE) RESERVES
-------- ------- ------- ------- --------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Proved developed producing...................... 4,767 125,751 154,353 $168,944
Proved developed non-producing.................. 1,430 64,149 72,729 53,285
Proved undeveloped.............................. 2,273 67,222 80,860 64,178
------ ------- ------- --------
Total proved.......................... 8,470 257,122 307,942 $286,407
====== ======= ======= ========
</TABLE>
There are numerous uncertainties inherent in estimating oil and natural gas
reserves and their values, including many factors beyond the control of the
producer. The reserve data set forth above represents estimates only. Reserve
engineering is a subjective process of estimating underground accumulations of
oil and natural gas that cannot be measured in an exact manner. The accuracy of
any reserve estimate is a function of the quality of available data and of
engineering and geological interpretation and judgment. As a result, estimates
of different engineers may vary. In addition, estimates of reserves are subject
to revision based on the results of drilling, testing and production subsequent
to the date of such estimate. Accordingly, reserve estimates are often different
from the quantities of oil and gas that are ultimately recovered. See "Risk
Factors -- Uncertainties in Estimating Reserves and Future Net Cash Flows."
In general, the volume of production from oil and natural gas properties
declines as reserves are depleted. Except to the extent the Company acquires
properties containing proved reserves or conducts successful exploration and
development activities, the proved reserves of the Company will decline as
reserves are produced. The Company's future oil and natural gas production is,
therefore, highly dependent upon its level of success in acquiring or developing
additional reserves. See "Risk Factors -- Replacement of Reserves."
PRIMARY OPERATING AREAS
The Company's activities are concentrated in three primary operating areas:
Southeast Texas, East Texas/North Louisiana and the Texas Gulf Coast. The
Company also owns interests in the Gulf of Mexico, South Louisiana, West Texas
and Mississippi. The following table summarizes the Company's estimated proved
oil and gas reserves by field as of December 31, 1995 on a pro forma basis for
the Black Stone Acquisition and the 1996 Dispositions. The Company's 20 largest
fields, as listed below, represent approximately 95% of the Company's pro forma
Present Value of Proved Reserves as of such date.
<TABLE>
<CAPTION>
PRESENT VALUE OF PROVED
RESERVES
NET OIL NET GAS -----------------------------
FIELD (MBBLS) (MMCF) (IN THOUSANDS) PERCENTAGE
- ----------------------------------------------- ------- ------- -------------- ----------
<S> <C> <C> <C> <C>
SOUTHEAST TEXAS
Double A Wells............................... 5,302 98,549 $148,588 52%
EAST TEXAS/NORTH LOUISIANA
Logansport................................... 94 23,501 $ 16,643
Beckville.................................... 176 25,406 14,581
Waskom....................................... 289 19,392 12,039
Longwood..................................... 110 13,249 9,797
Blocker...................................... 66 14,473 9,628
Ada.......................................... 13 5,191 7,082
Sugar Creek.................................. 81 6,624 4,575
Calhoun...................................... 32 2,005 3,446
Simsboro..................................... 5 3,988 3,086
Hico Knowles................................. 57 2,909 2,977
Other........................................ 12 9,019 5,916
----- ------- --------
935 125,757 89,770 31%
</TABLE>
27
<PAGE> 28
<TABLE>
<CAPTION>
PRESENT VALUE OF PROVED
RESERVES
NET OIL NET GAS -----------------------------
FIELD (MBBLS) (MMCF) (IN THOUSANDS) PERCENTAGE
- ----- ------- ------- -------------- ----------
<S> <C> <C> <C> <C>
TEXAS GULF COAST
Vienna....................................... -- 4,443 $ 4,666
El Campo..................................... 149 2,864 4,034
Mustang Island............................... 94 3,046 3,905
East White Point............................. 490 2,703 3,736
Redmond Creek................................ 148 1,500 3,247
Other........................................ 117 2,040 2,812
----- ------- --------
998 16,596 22,400 8%
OTHER AREAS
Ship Shoal 66................................ 410 288 $ 5,348
West Cameron Block 238....................... 4 4,595 5,163
Main Pass Blocks 21/25....................... 513 579 4,256
Lake LaRose.................................. 38 4,183 3,920
Other........................................ 270 6,575 6,962
----- ------- --------
1,235 16,220 25,649 9%
----- ------- -------- ---
Total................................... 8,470 257,122 $286,407 100%
===== ======= ======== ===
</TABLE>
SOUTHEAST TEXAS
The Company's largest concentration of proved reserves, representing 52% of
the Company's pro forma Present Value of Proved Reserves as of January 1, 1996,
is located in the Double A Wells field in Polk County, Texas. The Company
operates and owns interests in 19 producing wells (7.7 net) in this field. The
field includes high volume wells producing from the Upper Woodbine formation
with average gross production of 97 MMcf per day and 6,800 Bbls of oil per day
in September 1996. The Company is participating in the exploration of
undeveloped acreage adjacent to the Double A Wells field. Since its acquisition
of the properties, the Company participated in an exploratory dry hole,
successfully drilled a development well, and recently commenced drilling another
development well. Two or three additional wells in the Double A Wells field are
planned to further delineate the field during 1997.
EAST TEXAS/NORTH LOUISIANA
The second largest concentration of the Company's proved reserves is
located in East Texas/North Louisiana, and constitutes 31% of its pro forma
Present Value of Proved Reserves as of January 1, 1996. The Company owns
interests in 337 producing wells (186.5 net) in 19 fields, including Logansport,
Beckville, Waskom, Longwood, Blocker, West Simsboro and Ada fields. A major
portion of the Company's reserves are contained in the Travis Peak (Hosston in
Louisiana) formation and the Cotton Valley formation, which exhibit several
thousand feet of sand and shale sequences. The Company believes that success in
the Travis Peak and Cotton Valley formations can be enhanced by applying new
hydraulic fracturing and completion techniques, magnetic resonance imaging (MRI)
logging tools, and infill drilling.
The Company operates 45 wells and owns interests in 18 additional wells in
the Logansport field in DeSoto Parish, Louisiana. The Logansport field area
produces from multiple zones in the Hosston formation. In early 1996 the Company
initiated an infill drilling program to develop proved undeveloped reserves from
the Hosston sands. The Company has participated in drilling 10 infill
development wells in the first nine months of 1996, nine of which were
successful, and anticipates drilling a minimum of 12 additional infill
development wells in the fourth quarter of 1996 through 1997.
The Company operates approximately 135 wells in the Longwood, Beckville,
Blocker and Waskom fields in Northwest Louisiana and Northeast Texas. The
majority of these wells produce from the Hosston, Travis Peak and Cotton Valley
formations. During the first nine months of 1996, the Company drilled two
successful
28
<PAGE> 29
Travis Peak infill wells in the Longwood area and initiated a Cotton Valley
development drilling program, which includes a minimum of 13 wells in the fourth
quarter of 1996 through 1997.
As a result of a recently completed geologic study of the West Simsboro
field and adjacent areas, the Company has leased additional acreage in the field
and plans to drill a 10,500 foot exploratory well during the fourth quarter of
1996.
TEXAS GULF COAST
The Company's third largest operating area is the Texas Gulf Coast region.
The Company owns interests in 68 producing wells (36.8 net) in 10 fields, the
largest of which are the Vienna, El Campo, Mustang Island and East White Point
fields. Reserves in the Texas Gulf Coast area constitute 8% of the Company's pro
forma Present Value of Proved Reserves as of January 1, 1996. Major producing
formations include the Frio, Vicksburg, Yegua and Wilcox formations. The
Company's interest in this area focuses on fields that lie along the Frio trend.
The Company believes potential exists through the use of current technology for
additional oil and natural gas recovery in the older fields along this trend,
particularly in the deeper formations. Due to their structural complexity, many
of these fields are good candidates for the use of 3-D seismic technology that
can better define fault blocks and stratigraphic features in order to more
completely develop the remaining reserves.
In 1995 the Company and Marathon Oil Company formed a joint venture to
shoot 3-D seismic data on approximately 10,000 acres in the East White Point
area of Nueces Bay. The Company retained a 29% interest in wells to be developed
under the joint venture. Marathon and the Company plan to drill an exploratory
well in the fourth quarter of 1996 to test the Brigham (Frio) sand and a deeper
well to test the deep Frio sand in the first quarter of 1997.
ACQUISITION ACTIVITIES
ACQUISITION STRATEGY
The Company has concentrated its acquisition activity in Southeast Texas,
East Texas/North Louisiana and the Texas Gulf Coast regions. Using a strategy
that capitalizes on management's strong knowledge of, and experience in, these
regions, the Company seeks to selectively pursue acquisition opportunities where
the Company can evaluate the assets to be acquired in rigorous detail prior to
transaction completion. The Company evaluates a large number of prospective
properties according to certain internal criteria, including established
production and the properties' potential for operating control, exploitation and
low operating costs.
MAJOR PROPERTY ACQUISITIONS
Of the 16 property acquisitions completed by the Company since 1991, four
acquisitions described below account for 86% of the total acquisition cost and
84% of the total reserves acquired.
BLACK STONE ACQUISITION. In May 1996 the Company acquired 100% of the
capital stock of Black Stone Oil Company and interests in producing and
undeveloped oil and gas properties located in Southeast Texas for $104.0
million. The Company acquired interests in 19 producing wells (7.7 net) that are
located in the Double A Wells field in Polk County, Texas and is the operator of
the field. The net proved reserves acquired are estimated at 5.3 MMBbls of oil
and 98.5 Bcf of natural gas as of January 1, 1996, the effective date of the
acquisition.
SONAT ACQUISITION. In July 1995 the Company purchased interests in certain
producing oil and gas properties and natural gas gathering systems located in
East Texas and North Louisiana from Sonat for $50.6 million. The Company
acquired interests in 319 producing wells (188.0 net) along with interests in
gas gathering systems. The acquisition included interests in the Logansport,
Beckville, Waskom, Longwood, Blocker, Simsboro and Hico Knowles fields. The net
proved reserves acquired were estimated at 0.8 MMBbls of oil and 104.7 Bcf of
natural gas.
29
<PAGE> 30
STANFORD ACQUISITION. In November 1993 the Company acquired Stanford
Offshore Energy, Inc. ("Stanford") through a merger with a wholly owned
subsidiary, which now operates under the name Comstock Offshore Energy, Inc. The
Stanford stockholders were issued an aggregate of 1,760,000 shares of Common
Stock of the Company in the merger with a total value of $6.2 million and the
Company assumed approximately $16.5 million of indebtedness of Stanford.
Stanford had interests in 107 producing wells (58.8 net) located primarily in
Texas and offshore Gulf of Mexico. Major properties acquired include interests
in the Mustang Island, East White Point and Redmond Creek fields located on the
Texas Gulf Coast and West Cameron Block 238 in offshore Gulf of Mexico. The net
proved reserves acquired were estimated at 1.0 MMBbls of oil and 17.8 Bcf of
natural gas.
GOODRICH ACQUISITION. In November 1991 the Company acquired interests in 57
producing wells (27.3 net) located in 22 fields primarily in Louisiana and Texas
from Goodrich Oil Company and certain other working interest owners for $18.3
million. Major fields purchased in this acquisition include the Ada, Calhoun and
Sugar Creek fields in North Louisiana. The net proved reserves acquired were
estimated at 0.7 MMBbls of oil and 26.8 Bcf of natural gas.
As a result of its acquisitions, the Company has added 350.0 Bcfe of proved
oil and natural gas reserves as summarized in the following table:
<TABLE>
<CAPTION>
ACQUISITION ACQUISITION
PROVED RESERVES WHEN COST PER PRESENT VALUE OF COST AS A
ACQUISITION ACQUIRED(1) MCFE PROVED RESERVES PERCENTAGE OF
COST --------------------------- WHEN WHEN ACQUIRED(2) PRESENT VALUE OF
YEAR (000'S) (MBBLS) (MMCF) (MMCFE) ACQUIRED(2) (000'S) PROVED RESERVES
- ---- ----------- ------- ------ ------- ----------- ---------------- ---------------
<S> <C> <C> <C> <C> <C> <C> <C>
1996(3)........... $ 103,966 5,302 98,549 130,361 $0.80 $148,588 70%
1995.............. 56,081 1,859 108,432 119,585 0.47 85,706 65%
1994.............. 12,970 388 12,744 15,074 0.86 14,050 92%
1993(2)........... 26,928 2,250 28,349 41,848 0.64 33,502 80%
1992(2)........... 4,730 44 8,821 9,086 0.52 8,474 56%
1991.............. 20,862 689 29,868 34,002 0.61 27,298 76%
-------- ------ ------- ------- --------
Total... $ 225,537 10,532 286,763 349,956 $0.64 $317,618 71%
======== ====== ======= ======= ========
</TABLE>
- ---------------
(1) Based on reserve reports and prices at the end of the year in which the
acquisition occurred, as adjusted to reflect actual production from the
closing date of the respective acquisition to such year end.
(2) 1992 and 1993 amounts do not include amounts for acquisitions made by
Stanford prior to its acquisition by the Company, whereas amounts presented
in the Consolidated Financial Statements include amounts for acquisitions
made by Stanford prior to its acquisition by the Company in accordance with
the pooling of interests method of accounting.
(3) Through September 30, 1996. The effective date of the Black Stone
Acquisition was January 1, 1996. The information has not been adjusted to
reflect the production subsequent to the effective date.
30
<PAGE> 31
DRILLING ACTIVITY SUMMARY
During the three-year period ended December 31, 1995 and the nine months
ended September 30, 1996, the Company drilled or participated in the drilling of
development and exploratory wells as set forth in the table below:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31, NINE MONTHS
--------------------------------------- ENDED
SEPTEMBER
1993 1994 1995 30, 1996
----------- ----------- ----------- -----------
GROSS NET GROSS NET GROSS NET GROSS NET
----- --- ----- --- ----- --- ----- ---
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Development Wells:
Oil...................................... 14 1.7 -- -- 2 0.5 1 0.0
Gas...................................... 2 0.4 2 0.6 9 2.4 12 5.4
Dry...................................... 5 1.2 -- -- 2 0.7 1 1.0
-- --- -- --- -- --- -- ---
21 3.3 2 0.6 13 3.6 14 6.4
-- --- -- --- -- --- -- ---
Exploratory Wells:
Oil...................................... -- -- -- -- -- -- -- --
Gas...................................... -- -- -- -- -- -- -- --
Dry...................................... 5 0.8 -- -- -- -- 1 0.2
-- --- -- --- -- --- -- ---
-- - -- - -- - -- -
5 0.8 -- -- -- -- 1 0.2
-- --- -- --- -- --- -- ---
-- --- -- --- -- --- -- ---
Total Wells...................... 26 4.1 2 0.6 13 3.6 15 6.6
== === == === == === == ===
</TABLE>
In addition, three gross wells (1.8 net) were in the process of being
drilled at September 30, 1996. Subsequent to September 30, 1996, the Company
commenced the drilling of two development wells (1.3 net).
PRODUCING WELL SUMMARY
The following table sets forth the gross and net producing oil and natural
gas wells in which the Company owned an interest at September 30, 1996.
<TABLE>
<CAPTION>
OIL GAS
-------------- ---------------
GROSS NET GROSS NET
----- ---- ----- -----
<S> <C> <C> <C> <C>
Texas.................................................. 73 30.2 266 139.3
Louisiana.............................................. 26 10.0 166 81.6
Federal Offshore....................................... -- -- 23 10.4
Mississippi............................................ 1 0.1 2 0.3
--- ---- --- -----
Total wells.......................................... 100 40.3 457 231.6
=== ==== === =====
</TABLE>
The Company operates 331 of the 557 producing wells presented in the above
table.
31
<PAGE> 32
ACREAGE
The following table summarizes the Company's developed and undeveloped
leasehold acreage at September 30, 1996. Excluded is acreage in which the
Company's interest is limited to royalty or similar interests.
<TABLE>
<CAPTION>
DEVELOPED UNDEVELOPED
------------------- -----------------
GROSS NET GROSS NET
------- ------- ------ ------
<S> <C> <C> <C> <C>
Texas.......................................... 170,199 122,470 70,062 51,400
Louisiana...................................... 77,756 57,259 296 48
Federal Offshore............................... 12,160 5,760 -- --
Mississippi.................................... 1,360 210 -- --
------- ------- ------ ------
Total........................................ 261,475 185,699 70,358 51,448
======= ======= ====== ======
</TABLE>
Title to the Company's oil and natural gas properties is subject to
royalty, overriding royalty, carried and other similar interests and contractual
arrangements customary in the oil and gas industry, liens incident to operating
agreements and for current taxes not yet due, and other minor encumbrances. All
of the Company's oil and natural gas properties are pledged as collateral under
the Bank Credit Facility. As is customary in the oil and gas industry, the
Company is generally able to retain its ownership interest in undeveloped
acreage by production of existing wells, by drilling activity which establishes
commercial reserves sufficient to maintain the lease or by payment of delay
rentals.
MARKETS AND CUSTOMERS
The market for oil and natural gas produced by the Company depends on
factors beyond its control, including the extent of domestic production and
imports of oil and natural gas, the proximity and capacity of natural gas
pipelines and other transportation facilities, demand for oil and natural gas,
the marketing of competitive fuels and the effects of state and federal
regulation. The oil and gas industry also competes with other industries in
supplying the energy and fuel requirements of industrial, commercial and
individual consumers.
Substantially all of the Company's natural gas production is sold either on
the spot gas market on a month-to-month basis at prevailing spot market prices
or under long-term contracts based on current spot market gas prices. The
Company enters into natural gas price swap agreements to reduce its exposure to
natural gas price fluctuations. In 1995 the Company hedged approximately 25% of
its natural gas production. For the nine months ended September 30, 1996, the
Company hedged approximately 13% of its natural gas production.
The Company has entered into natural gas price swap agreements to hedge
approximately 0.9 Bcf of its natural gas production for the fourth quarter of
1996 at an average price of $1.90 per MMbtu. The swap agreements include
estimated delivery point basis adjustments to better equate the agreements to
the Company's expected well head prices to be received. The Company has no
hedges in place for 1997 or subsequent years.
All of the Company's oil production is sold at the well site on an "as
produced" basis at posted field prices tied to the spot oil markets.
During the year ended December 31, 1995, no single purchaser or group of
affiliated purchasers accounted for more than 10% of the Company's total oil and
natural gas sales. As a result of the Black Stone Acquisition, the Company's
sales to HPL Resources Company, a gas marketing subsidiary of Enron Corp.
("HPL"), accounted for approximately 23% of the Company's 1995 oil and natural
gas sales on a pro forma basis. The agreement with HPL is for a term expiring on
October 31, 2000. Pricing under the agreement is based on a percentage of spot
gas prices for natural gas delivered to the Houston Ship Channel.
32
<PAGE> 33
The Company is currently evaluating a potential sale of its gas gathering
and processing assets and third party gas marketing operations. Management
believes that any such transaction would not have a material impact on the
Company's results of operations or financial position.
COMPETITION
The oil and gas industry is highly competitive. Competitors include major
oil companies, other independent energy companies, and individual producers and
operators, many of which have financial resources, personnel and facilities
substantially greater than those of the Company. The Company faces intense
competition for the acquisition of oil and natural gas properties.
REGULATION
OIL AND GAS
The Company's operations are regulated by certain federal and state
agencies. In particular, oil and natural gas production and related operations
are or have been subject to price controls, taxes and other laws relating to the
oil and natural gas industry. The Company cannot predict how existing laws and
regulations may be interpreted by enforcement agencies or court rulings, whether
additional laws and regulations will be adopted, or the effect such changes may
have on its business or financial condition.
The Company's oil and gas exploration, production and related operations
are subject to extensive rules and regulations promulgated by federal, state and
local agencies. Failure to comply with such rules and regulations can result in
substantial penalties. The regulatory burden on the oil and gas industry
increases the Company's cost of doing business and affects its profitability.
Because such rules and regulations are frequently amended or reinterpreted, the
Company is unable to predict the future cost or impact of complying with such
laws.
The State of Texas and many other states require permits for drilling
operations, drilling bonds and reports concerning operations and impose other
requirements relating to the exploration and production of oil and gas. Such
states also have statutes or regulations addressing conservation matters,
including provisions for the unitization or pooling of oil and gas properties,
the establishment of maximum rates of production from oil and gas wells and the
regulation of spacing, plugging and abandonment of such wells. The statutes and
regulations of certain states limit the rate at which oil and gas can be
produced from the Company's properties.
Sales of natural gas by the Company are not regulated and are made at
market prices. However, the Federal Energy Regulatory Commission ("FERC")
regulates interstate and certain intrastate natural gas transportation rates and
service conditions, which affect the marketing of natural gas produced by the
Company, as well as the revenues received by the Company for sales of such
production. Since the mid-1980s, FERC has issued a series of orders, culminating
in Order Nos. 636, 636-A and 636-B ("Order 636"), that have significantly
altered the marketing and transportation of gas. Order 636 mandates a
fundamental restructuring of interstate pipeline sales and transportation
service, including the unbundling by interstate pipelines of the sales,
transportation, storage and other components of the city-gate sales services
such pipelines previously performed. One of FERC's purposes in issuing the
orders was to increase competition within all phases of the natural gas
industry. Order 636 and subsequent FERC orders issued in individual pipeline
restructuring proceedings have been the subject of appeals, the results of which
have generally been supportive of the FERC's open-access policy. Earlier this
year the United States Court of Appeals for the District of Columbia Circuit
largely upheld Order No. 636, et seq. Because further review of certain of these
orders is still possible, and other appeals remain pending, it is difficult to
predict the ultimate impact of the orders on the Company and its gas marketing
efforts. Generally, Order 636 has eliminated or substantially reduced the
interstate pipelines' traditional role as wholesalers of natural gas, and has
substantially increased competition and volatility in natural gas markets. While
significant regulatory uncertainty remains, Order 636 may ultimately enhance the
Company's ability to market and transport its gas, although it may also subject
the Company to greater competition and the more restrictive pipeline imbalance
tolerances and greater associated penalties for violation of such tolerances.
33
<PAGE> 34
Sales of oil and natural gas liquids by the Company are not regulated and
are made at market prices. The price the Company receives from the sale of these
products is affected by the cost of transporting the products to market.
Effective as of January 1, 1995, FERC implemented regulations establishing an
indexing system for transportation rates for interstate common carrier oil
pipelines, which, generally, would index such rates to inflation, subject to
certain conditions and limitations. These regulations could increase the cost of
transporting oil and natural gas liquids by interstate pipelines, although the
most recent adjustment generally decreased rates. These regulations have
generally been approved on judicial review. The Company is not able to predict
with certainty what effect, if any, these regulations will have on it, but,
other factors being equal, the regulations may, over time, tend to increase
transportation costs or reduce wellhead prices for oil and natural liquids.
The Company is required to comply with various federal and state
regulations regarding plugging and abandonment of oil and natural gas wells. The
Company provides reserves for the estimated costs of plugging and abandoning its
wells on a unit of production basis.
ENVIRONMENTAL
Various federal, state and local laws and regulations governing the
discharge of materials into the environment, or otherwise relating to the
protection of the environment, health and safety, affect the Company's
operations and costs. These laws and regulations sometimes require governmental
authorization before certain activities, limit or prohibit other activities
because of protected areas or species, impose substantial liabilities for
pollution related to Company operations or properties, and provide penalties for
noncompliance. In particular, the Company's exploration and production
operations, its activities in connection with storage and transportation of
crude oil and other liquid hydrocarbons, and its use of facilities for treating,
processing or otherwise handling hydrocarbons and related exploration and
production wastes are subject to stringent environmental regulation. As with the
industry generally, compliance with existing and anticipated regulations
increases the Company's overall cost of business. While these regulations affect
the Company's capital expenditures and earnings, the Company believes that such
regulations do not affect its competitive position in the industry because its
competitors are similarly affected by environmental regulatory programs.
Environmental regulations have historically been subject to frequent change and,
therefore, the Company is potentially unable to predict the future costs or
other future impacts of environmental regulations on its future operations. A
discharge of hydrocarbons or hazardous substances into the environment could
subject the Company to substantial expense, including the cost to comply with
applicable regulations that require a response to the discharge, such as
containment or cleanup, claims by neighboring landowners or other third parties
for personal injury, property damage or their response costs and penalties
assessed, or other claims sought, by regulatory agencies for response cost or
for natural resource damages.
The following are examples of some environmental laws that potentially
impact the Company and its operations.
WATER. The Oil Pollution Act ("OPA") was enacted in 1990 and amends
provisions of the Federal Water Pollution Control Act of 1972 ("FWPCA") and
other statutes as they pertain to prevention of and response to major oil
spills. The OPA subjects owners of facilities to strict, joint and potentially
unlimited liability for removal costs and certain other consequences of an oil
spill, where such spill is into navigable waters, or along shorelines. In the
event of an oil spill into such waters, substantial liabilities could be imposed
upon the Company. States in which the Company operates have also enacted similar
laws. Regulations are currently being developed under the OPA and similar state
laws that may also impose additional regulatory burdens on the Company.
The FWPCA imposes restrictions and strict controls regarding the discharge
of produced waters, other oil and gas wastes, any form of pollutant, and, in
some instances, storm water runoff, into waters of the United States. The FWPCA
provides for civil, criminal and administrative penalties for any unauthorized
discharges and, along with the OPA, imposes substantial potential liability for
the costs of removal, remediation or damages resulting from an unauthorized
discharge. State laws for the control of water pollution also provide civil,
criminal and administrative penalties and liabilities in the case of an
unauthorized discharge into state
34
<PAGE> 35
waters. The cost of compliance with the OPA and the FWPCA have not historically
been material to the Company's operations, but there can be no assurance that
changes in federal, state or local water pollution control programs will not
materially adversely effect the Company in the future. Although no assurances
can be given, the Company believes that compliance with existing permits and
compliance with foreseeable new permit requirements will not have a material
adverse effect on the Company's financial condition or results of operations.
AIR EMISSIONS. Amendments to the Federal Clean Air Act enacted in late 1990
(the "1990 CAA Amendments") require or will require most industrial operations
in the United States to incur capital expenditures in order to meet air
emissions control standards developed by the Environmental Protection Agency
("EPA") and state environmental agencies. The 1990 CAA Amendments impose a new
operating permit on major sources, and several of the Company's facilities may
require permits under this new program. Although no assurances can be given, the
Company believes implementation of the 1990 CAA Amendments will not have a
material adverse effect on the Company's financial condition or results of
operations.
SOLID WASTE. The Company generates non-hazardous solid wastes that are
subject to the requirements of the Federal Resource Conservation and Recovery
Act ("RCRA") and comparable state statutes. The EPA and the states in which the
Company operates are considering the adoption of stricter disposal standards for
the type of non-hazardous wastes generated by the Company. RCRA also governs the
generation, management, and disposal of hazardous wastes. At present, the
Company is not required to comply with a substantial portion of the RCRA
requirements because the Company's operations generate minimal quantities of
hazardous wastes. However, it is anticipated that additional wastes, which could
include wastes currently generated during the operations, could in the future be
designated as "hazardous wastes." Hazardous wastes are subject to more rigorous
and costly disposal and management requirements than are non-hazardous wastes.
Such changes in the regulations may result in additional capital expenditures or
operating expenses by the Company.
SUPERFUND. The Comprehensive Environmental Response, Compensation, and
Liability Act ("CERCLA"), also known as "Superfund", imposes liability, without
regard to fault or the legality of the original act, on certain classes of
persons in connection with the release of a "hazardous substance" into the
environment. These persons include the current owner or operator of any site
where a release historically occurred and companies that disposed or arranged
for the disposal of the hazardous substances found at the site. CERCLA also
authorizes the EPA and, in some instances, third parties to act in response to
threats to the public health or the environment and to seek to recover from the
responsible classes of persons the costs they incur. In the course of its
ordinary operations, the Company may have managed substances that may fall
within CERCLA's definition of a "hazardous substance." The Company may be
jointly and severally liable under CERCLA for all or part of the costs required
to clean up sites where the Company disposed of or arranged for the disposal of
these substances. This potential liability extends to properties that the
Company owned or operated, as well as to properties owned and operated by others
at which disposal of the Company's hazardous substances occurred.
The Company may also fall into the category of the "current owner or
operator." The Company currently owns or leases numerous properties that for
many years have been used for the exploration and production of oil and gas.
Although the Company believes it has utilized operating and disposal practices
that were standard in the industry at the time, hydrocarbons or other wastes may
have been disposed of or released by the Company on or under the properties
owned or leased by the Company. In addition, many of these properties have been
previously owned or operated by third parties who may have disposed of or
released hydrocarbons or other wastes at these properties. Under CERCLA, and
analogous state laws, the Company could be subject to certain liabilities and
obligations, such as being required to remove or remediate previously disposed
wastes (including wastes disposed of or released by prior owners or operators),
to clean up contaminated property (including contaminated groundwater) or to
perform remedial plugging operations to prevent future contamination.
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<PAGE> 36
OFFICE AND OPERATIONS FACILITIES
The Company leases office space in Dallas, Texas. The Dallas lease covers
13,525 square feet at a monthly rate of $18,475 during 1996. The lease expires
on September 30, 1999. The Company also owns or leases five production offices
and yard facilities in Marshall, Bay City, Dumas, and Livingston, Texas and
Logansport, Louisiana.
EMPLOYEES
At September 30, 1996, the Company had 56 employees and utilized contract
employees for certain of its oil field operations. The Company considers its
employee relations to be satisfactory.
LEGAL PROCEEDINGS
The Company is not a party to any legal proceedings which management
believes will have a material adverse effect on the Company's consolidated
results of operations or financial condition.
36
<PAGE> 37
MANAGEMENT
DIRECTORS, EXECUTIVE OFFICERS AND OTHER MANAGEMENT
The following table sets forth certain information concerning the executive
officers, directors and other management of the Company.
<TABLE>
<CAPTION>
NAME AGE POSITION WITH COMPANY
----------------------------- --- ------------------------------------------------------
<S> <C> <C>
DIRECTORS AND EXECUTIVE OFFICERS
M. Jay Allison............. 40 President, Chief Executive Officer and Director
Roland O. Burns............ 36 Senior Vice President, Chief Financial Officer,
Secretary and Treasurer
James L. Menke............. 45 Vice President of Operations
Richard S. Hickok.......... 70 Director
Franklin B. Leonard........ 69 Director
Harold R. Logan............ 75 Chairman of the Board of Directors
Cecil E. Martin, Jr. ...... 55 Director
David W. Sledge............ 39 Director
OTHER MANAGEMENT
Michael W. Taylor.......... 43 Director of Acquisitions and Chief Reservoir Engineer
Richard G. Powers.......... 42 Land Manager
Daniel K. Presley.......... 36 Controller and Assistant Treasurer
</TABLE>
M. JAY ALLISON has been a director of the Company since 1987, and President
and Chief Executive Officer of the Company since 1988. From 1987 to 1988, Mr.
Allison served as Vice President and Secretary of the Company. From 1981 to
1987, he was a practicing oil and gas attorney with the firm of Lynch, Chappell
& Alsup in Midland, Texas. In 1983, Mr. Allison co-founded a private independent
oil and gas company, Midwood Petroleum, Inc., which was active in the
acquisition and development of oil and gas properties from 1983 to 1987. He
received B.B.A., M.S. and J.D. degrees from Baylor University in 1978, 1980 and
1981, respectively. Mr. Allison currently serves on the Board of Trustees of
Howard Payne University.
ROLAND O. BURNS has been Senior Vice President of the Company since 1994,
Chief Financial Officer and Treasurer since 1990 and Secretary since 1991. From
1982 to 1990, Mr. Burns was employed by the public accounting firm, Arthur
Andersen LLP. During his tenure with Arthur Andersen LLP, Mr. Burns worked
primarily in the firm's oil and gas audit practice. Mr. Burns received B.A. and
M.A. degrees from the University of Mississippi in 1982 and is a Certified
Public Accountant.
JAMES L. MENKE has been Vice President of Operations of the Company since
March 1994. From 1987 to 1994, Mr. Menke was Manager of Engineering for Atropos
Exploration Company. From 1973 to 1986, Mr. Menke held engineering positions
with Pennzoil Company, Gruy Management Services Company, Maynard Oil Company,
and Santa Fe Minerals. Mr. Menke received a B.S. degree in Petroleum Engineering
from Texas A & M University in 1973 and is a Registered Professional Engineer.
RICHARD S. HICKOK has been a director of the Company since 1987. From 1948
to 1983, he was employed by the international accounting firm of Main Hurdman
where he retired as Chairman. From 1978 to 1980, Mr. Hickok served as a Trustee
of the Financial Accounting Foundation and has extensive involvement serving on
various committees of the American Institute of Certified Public Accountants. He
currently serves as a director of Marsh & McLennan Company, Inc., Alpine Lace
Brands, Inc., Marcam, Inc. and Projectavision, Inc. Mr. Hickok holds a B.S.
degree from the Wharton School of the University of Pennsylvania.
FRANKLIN B. LEONARD has been a director of the Company since 1960. From
1961 to 1994, Mr. Leonard served as President of Crossley Surveys, Inc., a New
York based company which conducted statistical surveys. Mr. Leonard's family's
involvement in the Company spans four generations dating back to the 1880's when
Mr. Leonard's great grandfather was a significant shareholder of the Company.
Mr. Leonard also served as a director of Glen Ridge Savings and Loan Association
from 1968 to 1990. Mr. Leonard holds a B.S. degree from Yale University.
37
<PAGE> 38
HAROLD R. LOGAN has served as Chairman of the Board of Directors since
1987. From 1960 to 1986, Mr. Logan was employed by W.R. Grace & Co. at various
positions including Vice Chairman of the Board of Directors and head of the W.R.
Grace & Co. Energy Division. From 1953 to 1960 Mr. Logan was a Budget Director
in the Department of Defense during the Eisenhower Administration. He is
currently serving as a trustee of the Neuberger and Berman Income Funds and is a
past director of the Whitman Corporation and Chelsea Industries. Mr. Logan holds
a B.S. degree from Oklahoma State University.
CECIL E. MARTIN, JR. has been a director of the Company since 1988. Mr.
Martin has been a significant investor since 1987. From 1973 to 1991 he served
as Chairman of a public accounting firm in Richmond, Virginia. Mr. Martin also
serves as a director for Ten-Key, Inc. Mr. Martin holds a B.B.A. degree from Old
Dominion University and is a Certified Public Accountant.
DAVID W. SLEDGE was elected to the Board of Directors of the Company in May
1996. Mr. Sledge served as President of Gene Sledge Drilling Corporation, a
privately held contract drilling company based in Midland, Texas until its sale
in October 1996. Mr. Sledge served Gene Sledge Drilling Corporation in various
capacities from 1979 to 1996. Mr. Sledge is director of the International
Association of Drilling Contractors and is a past chairman of the Permian Basin
chapter of this association. He received a B.B.A. degree from Baylor University
in 1979.
MICHAEL W. TAYLOR is Director of Acquisitions and Chief Reservoir Engineer.
Prior to joining the Company in September 1994, Mr. Taylor had been an
independent oil and gas producer and petroleum consultant for the previous
fifteen years. Mr. Taylor is a registered professional engineer and he received
a B.S. degree in Petroleum Engineering from Texas A&M University in 1974.
RICHARD G. POWERS joined the Company as Land Manager in October 1994. Mr.
Powers has over 17 years experience as a petroleum landman. Prior to joining the
Company, Mr. Powers was employed for 10 years as Land Manager for Bridge Oil
(U.S.A.), Inc. and its predecessor Pinoak Petroleum, Inc. Mr. Powers received a
B.B.A. degree in 1976 from Texas Christian University.
DANIEL K. PRESLEY is the Controller and Assistant Treasurer and has been
with the Company since December 1989. Prior to joining the Company, Mr. Presley
had six years of business and finance experience with several independent oil
and gas companies including AmBrit Energy, Inc. Prior thereto, Mr. Presley spent
two and one-half years with B.D.O. Seidman, a public accounting firm. Mr.
Presley has a B.B.A. from Texas A&M University.
EMPLOYMENT AGREEMENTS
Effective July 1, 1996, the Company entered into employment agreements with
M. Jay Allison, the President and Chief Executive Officer of the Company, and
Roland O. Burns, Senior Vice President, Chief Financial Officer, Secretary and
Treasurer of the Company. Under the agreements, the Company agreed to employ
each of Mr. Allison and Mr. Burns for a period of 12 months at a minimum base
rate of $245,000, and $132,500 per annum, respectively. Each of the agreements
provides for the payment of severance benefits in an amount equal to three times
the existing annual base salary of the employee upon (i) a change in control
followed by (ii) the occurrence of certain specified events, including the
assignment of the employee to duties inconsistent with his position immediately
prior to the change in control, a reduction in the employee's salary, requiring
the employee to be relocated, failure of a successor to the Company to assume
the obligations of the Company under the agreement, failure of the Company to
re-elect the employee to the offices held by him immediately prior to a change
in control and a breach by the Company (or any successor) of any provisions of
the agreement. The severance benefit payments are payable in cash in equal
payments (without interest over a period not to exceed 12 months). As defined in
the agreements, a "change in control" is deemed to have taken place if (a)
without the approval or recommendation of a majority of the then existing Board
of Directors of the Company, a third person causes or brings about the removal
or resignation of a majority of the then existing members of the Board or if a
third person causes or brings about an increase in the size of the Board such
that the then existing members of the Board thereafter represent a minority of
the total number of persons comprising the entire Board; (b) a third person,
including a group, becomes the beneficial owner of shares of any class of the
Company's stock having 30% or more of the total number of votes that may be cast
38
<PAGE> 39
for the election of directors of the Company; (c) any shares or any class of the
Company's stock are purchased pursuant to a tender or exchange offer (other than
an offer by the Company); or (d) the Company's stockholders approve a merger or
other business combination of the Company with or into another corporation
pursuant to which the Company will not survive or will survive only as a
subsidiary of another corporation, or the sale or other disposition of all or
substantially all of the assets of the Company, or any combination of the
foregoing.
COMPENSATION OF EXECUTIVE OFFICERS
The following table sets forth certain information regarding compensation
earned during each of the Company's last three fiscal years by the Company's
Chief Executive Officer and the other executive officers of the Company.
SUMMARY COMPENSATION TABLE
<TABLE>
<CAPTION>
LONG-TERM
COMPENSATION
AWARDS
------------
SECURITIES
ANNUAL COMPENSATION UNDERLYING ALL OTHER
NAME AND ----------------------------- OPTIONS/ COMPEN-
PRINCIPAL POSITION YEAR SALARY BONUS SARS SATION(1)(2)
- -------------------------------------- ---- --------- -------- ------------ ---------------
<S> <C> <C> <C> <C> <C>
M. Jay Allison, 1995 $ 245,000 $155,000 50,000 $ 3,200
President and Chief 1994 241,500 130,000 -- --
Executive Officer 1993 241,500 110,000 115,000 --
Roland O. Burns, 1995 128,000 40,000 22,500 1,909
Sr. Vice President and 1994 123,500 30,000 -- --
Chief Financial Officer 1993 107,000 35,000 29,500 --
James L. Menke, 1995 90,000 30,000 10,000 1,331
Vice President of 1994 59,924 15,000 -- --
Operations (3) 1993 -- -- -- --
</TABLE>
- ---------------
(1) The value of all perquisites provided to each executive officer by the
Company did not exceed the lesser of $50,000 or 10% of such officer's salary
and bonus for the year.
(2) Represents the Company's matching contributions under the Company's 401(k)
Profit Sharing Plan.
(3) Mr. Menke was elected Vice President of Operations on March 21, 1994.
The following table sets forth certain information regarding stock options
granted during 1995 to the named executive officers of the Company.
<TABLE>
<CAPTION>
INDIVIDUAL GRANTS POTENTIAL
------------------------- REALIZABLE VALUE AT
PERCENT OF ASSUMED ANNUAL
NUMBER OF TOTAL RATES OF STOCK
SECURITIES OPTIONS PRICE APPRECIATION
UNDERLYING GRANTED TO EXERCISE OR FOR OPTION
OPTIONS EMPLOYEES IN BASE PRICE EXPIRATION -------------------
NAME GRANTED FISCAL YEAR PER SHARE DATE 5% 10%
- --------------------------- ---------- ------------ ----------- -------------- ------- -------
<S> <C> <C> <C> <C> <C> <C>
M. Jay Allison............. 50,000 51.3% $3.00 August 1, 2000 $41,442 $91,577
Roland O. Burns............ 22,500 23.1 3.00 August 1, 2000 18,649 41,209
James L. Menke............. 10,000 10.3 3.00 August 1, 2000 8,288 18,315
</TABLE>
39
<PAGE> 40
The following table sets forth certain information with respect to the
value of the named executive officers' unexercised options at December 31, 1995.
No options were exercised by the named executive officers during 1995.
<TABLE>
<CAPTION>
NUMBER OF SECURITIES
UNDERLYING UNEXERCISED VALUE OF UNEXERCISED
OPTIONS AT FISCAL IN-THE-MONEY OPTIONS
YEAR-END AT FISCAL YEAR-END(1)
----------------------------- -----------------------------
NAME EXERCISABLE UNEXERCISABLE EXERCISABLE UNEXERCISABLE
- ------------------------------------------ ----------- ------------- ----------- -------------
<S> <C> <C> <C> <C>
M. Jay Allison............................ 365,000 50,000 $ 1,190,625 $ 181,250
Roland O. Burns........................... 76,750 25,000 233,594 90,625
James L. Menke............................ 10,000 -- 26,250 --
</TABLE>
- ---------------
(1) The last sale price for a share of Common Stock as reported by the Nasdaq
National Market on December 29, 1995 was $5.625 and the exercise prices of
the options in this table ranged from $2.00 to $3.00 per share.
On May 15, 1996, the stockholders of the Company approved an amendment to
the Company's 1991 Long-term Incentive Plan (the "Plan"). Pursuant to the
amendment, (i) the total number of shares of Common Stock reserved for all
awards under the Plan was increased from 1,160,000 to 2,400,000 (plus 10% of the
number of new shares of Common Stock issued other than pursuant to the Plan) and
(ii) the number of shares of Common Stock available for grant of options to
non-employee directors was increased from 270,000 to 525,000.
During 1996 options have been granted under the Plan (each with an exercise
price equal to the fair market value of the Common Stock on the date of grant)
to the executive officers as set forth below. With respect to the Company's 1995
performance, the Board of Directors on January 25, 1996 approved the following
grants of options to purchase the number of shares of Common Stock indicated:
Mr. Allison (155,000 shares); Mr. Burns (40,000 shares); and Mr. Menke (30,000
shares). These options have an exercise price of $4.81 per share and expire on
August 1, 2001. On May 15, 1996, the Board approved the following grants of
options to purchase the number of shares of Common Stock indicated: Mr. Allison
(125,000 shares); Mr. Burns (32,500 shares); and Mr. Menke (15,000 shares).
These options have an exercise price of $6.56 per share and expire on December
1, 2001. On September 10, 1996, the Board approved the following additional
stock option grants to: Mr. Allison (885,000 shares); Mr. Burns (220,000 shares)
and Mr. Menke (57,500 shares). These options vest over a period of four years,
have an exercise price of $11.00 per share and expire five years after full
vesting.
COMPENSATION OF DIRECTORS
The Company pays annual fees to directors who are not employees of the
Company and reimburses such directors for expenses in attending meetings. The
Company pays an annual fee of $23,000 to the Chairman of the Board of Directors,
an annual fee of $21,000 to directors who chair committees, and an annual fee of
$18,000 to the remaining directors. The Company also pays Mr. Logan and Mr.
Martin for additional services provided to the Company under consulting
agreements which provide for annual payments of $24,000 and $18,000,
respectively. Under a plan established by the Board of Directors, each director
can make an annual election to receive his director and consulting fees in cash
or in the equivalent number of shares of Common Stock at the then current market
price of Common Stock. In January 1996 the Company issued 29,714 shares of
Common Stock, at its then current market value of $4.8125 per share, to the
non-employee directors in full payment of director fees for 1996 aggregating
$101,000 and for amounts due to Mr. Logan and Mr. Martin under the consulting
agreements aggregating $42,000. In May 1996, the Company issued shares of Common
Stock, at its then current market value of $6.5625 per share, to Mr. Sledge in
payment of director fees for 1996 of $11,250.
Under the Plan, each non-employee director receives on the date of initial
election or appointment to the Board of Directors options to acquire 10,000
shares of Common Stock. In addition, each non-employee director receives at each
annual meeting of stockholders so long as such person remains a director options
to acquire 10,000 shares of Common Stock. The exercise price equals the fair
market value on the date of grant.
40
<PAGE> 41
PRINCIPAL AND SELLING STOCKHOLDERS
The following table sets forth certain information, as of November 25,
1996, and as adjusted to give effect to the issuance and sale of the Common
Stock offered hereby, with respect to the beneficial ownership of Common Stock
by (i) each current executive officer of the Company named in the Summary
Compensation Table set forth herein, (ii) each director of the Company, (iii)
all directors and executive officers of the Company as a group, (iv) each person
known by the Company to be the beneficial owner of 5% or more of the Common
Stock, and (v) each Selling Stockholder. Except as otherwise specified, the
named beneficial owner has sole voting and investment power.
<TABLE>
<CAPTION>
SHARES BENEFICIALLY
OWNED SHARES BENEFICIALLY
PRIOR TO THE OWNED AFTER
OFFERING SHARES TO BE THE OFFERING
-------------------- SOLD IN --------------------
NAME(1) NUMBER PERCENT THE OFFERING NUMBER PERCENT
- --------------------------------------------------- --------- ------- ------------ --------- -------
<S> <C> <C> <C> <C> <C>
M. Jay Allison(2).................................. 1,047,373 5.71 153,239 894,134 3.75
Roland O. Burns(2)................................. 208,250 1.17 30,000 178,250 *
James L. Menke(2).................................. 55,000 * -- 55,000 *
Richard S. Hickok(2)(3)............................ 95,556 * -- 95,556 *
Franklin B. Leonard(2)............................. 150,811 * 20,000 130,811 *
Harold R. Logan(2)................................. 178,489 1.01 65,000 113,489 *
Cecil E. Martin, Jr.(2)(4)......................... 375,536 2.11 15,000 360,536 1.55
David W. Sledge(2)................................. 21,714 * -- 21,714 *
--------- ------------ ---------
All directors and executive officers as a group
(8 persons)...................................... 2,132,729 11.34 283,239 1,849,490 7.61
========= =========== =========
The TCW Group, Inc.:(5)
Trust Company of the West, as Trustee of the TCW
Debt and Royalty Fund IVA...................... 202,345 1.13 99,828 102,517 *
Trust Company of the West, as Custodian for
Columbia University............................ 168,620 * 166,379 2,241 *
Trust Company of the West, as Custodial Agent for
TCW Debt and Royalty Fund IVC.................. 233,568 1.30 115,232 118,336 *
The Chase Manhattan Bank, as Custodian for The
Trustees of The Leland Stanford Junior
University..................................... 337,243 1.87 166,380 170,863 *
Trust Company of the West, as Custodial Agent for
TCW Debt and Royalty Fund IVB.................. 540,601 2.97 266,708 273,893 1.17
Harris Trust and Savings Bank, as Custodian for
the Searle Trusts Limited Partnership X........ 168,620 * 83,190 85,430 *
Harris Trust and Savings Bank, as Custodian for
the John G. Searle Charitable Trusts
Partnership.................................... 67,449 * 33,276 34,173 *
Trust Company of the West, as Custodian for The
City and County Employees' Retirement System of
San Francisco.................................. 77,078 * 38,026 39,052 *
Trust Company of the West, as Investment Manager
for General Mills, Inc......................... 965,209 5.18 476,190 489,019 2.07
Harris Trust and Savings Bank, as Trustee for
Delta Air Lines, Inc........................... 134,898 * 66,552 68,346 *
--------- ------------ ---------
2,895,631 14.10 1,511,761 1,383,870 5.64
========= =========== =========
</TABLE>
(footnotes on following page)
41
<PAGE> 42
- ---------------
* Indicates less than one percent.
(1) Unless otherwise indicated, the address of each beneficial owner is c/o
Comstock Resources, Inc., 5005 LBJ Freeway, Suite 1000, Dallas, Texas 75244.
(2) Includes shares issuable pursuant to stock options which are presently
exercisable or exercisable within 60 days in the following amounts: Mr.
Allison -- 670,000 shares; Mr. Burns -- 154,250 shares; Mr. Menke -- 55,000
shares; Mr. Hickok -- 41,500 shares; Mr. Leonard -- 50,500 shares; Mr.
Logan -- 50,500 shares; Mr. Martin -- 41,500 shares; and Mr.
Sledge -- 20,000 shares.
(3) Includes 32,572 shares held by a corporation owned 90% by Mr. Hickok's wife
and 10% by Mr. Hickok's children.
(4) Includes 135,632 shares and options to purchase 42,875 shares held by Mr.
Martin's wife individually or as trustee on behalf of family trusts and
3,018 shares held by Mr. Martin as custodian for family members.
(5) The address of The TCW Group Inc. ("TCW"), and each beneficial owner listed
thereunder, is c/o The TCW Group, Inc., 865 South Figueroa Street, Los
Angeles, California 90017. TCW is the parent of the trustee, general partner
or investment manager for the listed owners.
CERTAIN TRANSACTIONS
In connection with the issuance of the Series 1995 Preferred, the Company
granted the holders of the Series 1995 Preferred (the "Series 1995 Holders")
certain demand and "piggyback" registration rights with respect to the Common
Stock issuable upon conversion of the Series 1995 Preferred. In connection with
the Offering, TCW has advised the Company that the Series 1995 Holders intend to
convert 793,677 shares of Series 1995 Preferred into 1,511,761 shares of Common
Stock, exercise their "piggyback" registration rights and sell such shares in
the Offering. The Company is required to pay all expenses (other than
underwriting discounts and commissions) relating to the registration of the
shares of Common Stock to be sold by the Series 1995 Holders. The Company has
additionally agreed to pay all registration expenses (other than underwriting
discounts and commissions) of the other Selling Stockholders in the Offering.
The Company serves as general partner of Comstock DR-II Oil & Gas
Acquisition Limited Partnership ("DR-II"). In 1995 the Company received $87,000
in management fees and had a receivable from DR-II of approximately $380,000 at
December 31, 1995. TCW is an investment manager for certain investors which have
an interest in DR-II.
DESCRIPTION OF CAPITAL STOCK
The authorized capital stock of the Company consists of 30,000,000 shares
of Common Stock and 5,000,000 shares of preferred stock, $10.00 par value per
share (the "Preferred Stock"). At November 25, 1996, there were issued and
outstanding 17,679,869 shares of Common Stock and 1,500,000 shares of Preferred
Stock designated as the Series 1995 Preferred. Options to purchase 2,937,680
shares of Common Stock were also outstanding at that date. In the aggregate,
5,794,823 shares of Common Stock have been reserved for issuance pursuant to the
exercise of currently outstanding options and the conversion of the Series 1995
Preferred.
COMMON STOCK
Subject to the prior rights of the Series 1995 Preferred and any other
shares of Preferred Stock that may be issued from time to time, and except as
otherwise set forth below, the shares of Common Stock of the Company (1) are
entitled to such dividends as may be declared by the Board of Directors, in its
discretion, out of funds legally available therefor; (2) are entitled to one
vote per share on matters voted upon by the stockholders and have no cumulative
voting rights; (3) have no preemptive or conversion rights; (4) are not subject
to, or entitled to the benefits of, any redemption or sinking fund provision;
and (5) are entitled, upon liquidation, to receive the assets of the Company
remaining after the payment of corporate debts and the
42
<PAGE> 43
satisfaction of any liquidation preferences of the Series 1995 Preferred and any
other Preferred Stock, if issued. Although the Company's Articles of
Incorporation do not deny preemptive rights to stockholders, under Nevada law no
stockholders have preemptive rights with respect to shares that, upon issuance,
are registered under Section 12 of the Exchange Act. The Common Stock is
currently registered under Section 12 of the Exchange Act.
Because the shares of Common Stock do not have cumulative voting rights,
the holders of a majority of the shares voting for the election of directors can
elect all members of the class of the Company's classified Board of Directors
that are to be elected at a meeting of the stockholders, subject to any rights
of the holders of the Series 1995 Preferred. See "-- Preferred Stock."
PREFERRED STOCK
The Board of Directors is empowered, without approval of the stockholders,
to cause shares of the Company's authorized Preferred Stock to be issued in one
or more classes or series, from time to time, with the number of shares of each
class or series and the rights, preferences and limitations of each class or
series to be determined by it. Among the specific matters that may be determined
by the Board of Directors are the rate of dividends, redemption and conversion
prices, terms and amounts payable in the event of liquidation and voting rights.
Shares of Preferred Stock may, in the Board of Directors' sole determination, be
issued with voting rights greater than one vote per share. Issuance of shares of
Preferred Stock could involve dilution of the equity of the holders of Common
Stock and further restrict the rights of such stockholders to receive dividends.
SERIES 1995 PREFERRED. On June 30, 2000 and on each June 30 thereafter, so
long as any shares of the Series 1995 Preferred are outstanding, the Company is
obligated to redeem 300,000 shares of the Series 1995 Preferred at $10.00 per
share plus accrued and unpaid dividends thereon. The mandatory redemption price
may be paid either in cash or in shares of Common Stock, at the option of the
Company. If the Company elects to pay the mandatory redemption price in shares
of Common Stock, the Common Stock will be valued at 80% of the lower of the
Common Stock's 5 day or 30 day average closing price (immediately prior to the
date of redemption). The holders of the Series 1995 Preferred have the right, at
their option and at any time, to convert all or any part of such shares into
shares of Common Stock. The conversion price of the Series 1995 Preferred as of
the date of this Prospectus is $5.25 per share of Common Stock. The Company has
the option to redeem the shares of the Series 1995 Preferred at a price that
would provide the holders with a specified rate of return on their original
investment.
In the event of dissolution, liquidation or winding-up of the Company, the
holders of the Series 1995 Preferred are entitled, after payments of all amounts
payable to the holders of any Preferred Stock senior to the Series 1995
Preferred, to receive out of the assets remaining $10.00 per share, together
with all dividends thereon accrued or in arrears, whether or not declared,
before any payment is made or assets set apart for payment to the holders of the
Common Stock.
The holders of the Series 1995 Preferred are each entitled to vote with the
holders of Common Stock on all matters submitted for a vote of the holders of
shares of Common Stock on an "as converted" basis. Upon the occurrence of an
"event of noncompliance" within the meaning of the terms of the Series 1995
Preferred, the holders of the Series 1995 Preferred have the right (for so long
as such event of noncompliance continues) to elect two additional directors to
the Board of Directors of the Company. An "event of noncompliance" includes (i)
the failure to pay in the aggregate four quarterly dividends on such series,
(ii) the failure to redeem such series in accordance with its terms, (iii) a
default by the Company on certain indebtedness, (iv) M. Jay Allison ceasing to
be the chief executive officer of the Company and (v) the commencement of a
bankruptcy or similar proceeding by or against the Company or any of its
significant subsidiaries. Holders of the Series 1995 Preferred also have the
right to approve (1) a merger of the Company where the Company is not the
surviving corporation, (2) the issuance of more than 20% of the Common Stock in
connection with a merger or acquisition, (3) the sale or disposition of
substantially all of the Company's assets or (4) payment of any dividend or
distribution, on or for the redemption of Common Stock in excess of $50,000 a
year.
43
<PAGE> 44
STOCKHOLDERS' RIGHTS PLAN
On December 4, 1990, the Company's Board of Directors adopted the Company's
Stockholders' Rights Plan (the "Rights Plan") and the Company declared a
dividend distribution of one preferred stock purchase right (a "Right") for each
outstanding share of Common Stock. Each Right entitles the registered holder to
purchase from the Company one one-hundredth of a share of Series A Junior
Participating Preferred Stock, $10.00 par value per share, at an exercise price
of $15.00 (the "Purchase Price") per one one-hundredth of a share of Preferred
Stock, subject to adjustment. The description and terms of the Rights are set
forth in a Rights Agreement (the "Rights Agreement") between the Company and
American Stock Transfer and Trust Company, as successor Rights Agent.
The Rights are initially evidenced by the Common Stock certificates as no
separate Rights certificates have been distributed. The Rights separate from the
Common Stock and a "Distribution Date" will occur at the close of business on
the earliest of (i) the tenth business day following a public announcement that
a person or group of affiliated or associated persons (an "Acquiring Person")
has acquired, or obtained the right to acquire, beneficial ownership of 20% or
more of the outstanding shares of Common Stock (the "Stock Acquisition Date"),
(ii) the tenth business day (or such later date as may be determined by action
of the Board of Directors) following the commencement of a tender offer or
exchange offer that would result in a person or group beneficially owning 20% or
more of the outstanding shares of Common Stock or (iii) the tenth business day
after the Board of Directors of the Company determines that any individual,
firm, corporation, partnership or other entity (each a "Person"), alone or
together with its affiliates and associates, has become the beneficial owner of
an amount of Common Stock which a majority of the continuing directors who are
not officers of the Company determines to be substantial (which amount shall in
no event be less than 10% of the shares of Common Stock outstanding) and at
least a majority of the continuing directors who are not officers of the
Company, after reasonable inquiry and investigation, including consultation with
such Person as the directors shall deem appropriate, shall determine that such
beneficial ownership by such Person (an "Adverse Person") is intended to cause
the Company to repurchase the Common Stock beneficially owned by such Person or
to cause pressure on the Company to take action or enter into a transaction
intended to provide such Person with short-term financial gain under
circumstances where the directors determine that the best long-term interests of
the Company and its stockholders would not be served by taking such action or
entering into such transaction or series of transactions at that time, or that
such beneficial ownership is causing or is reasonably likely to cause a material
adverse impact on the Company. The Rights are not exercisable until the
Distribution Date and will expire at the close of business on December 17, 2000,
unless earlier redeemed by the Company.
If (i) a Person becomes the beneficial owner of 20% or more of the then
outstanding shares of Common Stock (except (a) pursuant to certain offers for
all outstanding shares of Common Stock approved by at least a majority of the
continuing directors who are not officers of the Company or (b) solely due to a
reduction in the number of shares of Common Stock outstanding as a result of the
repurchase of shares of Common Stock by the Company) or (ii) the Board of
Directors determines that a Person is an Adverse Person, each holder of a Right
will thereafter have the right to receive, upon exercise, Common Stock (or, in
certain circumstances, cash, property or other securities of the Company) having
a value equal to two times the exercise price of the Right. Notwithstanding any
of the foregoing, following the occurrence of either of the events set forth in
this paragraph, all Rights that are, or (under certain circumstances specified
in the Rights Agreement) were, beneficially owned by any Acquiring Person or
Adverse Person will be null and void.
If at any time following the Stock Acquisition Date, (i) the Company is
acquired in a merger or other business combination transaction in which the
Company is not the surviving corporation, or in which the Company is the
surviving corporation, but its Common Stock is changed or exchanged (other than
a merger which follows an offer described in clause (i)(a) of the preceding
paragraph), or (ii) more than 50% of the Company's assets, cash flow or earning
power is sold or transferred, each holder of a Right (except Rights which
previously have been voided as set forth above) shall thereafter have the right
to receive upon exercise, Common Stock of the acquiring company having a value
equal to two times the exercise price of the Right.
44
<PAGE> 45
At any time after the earlier to occur of (i) an Acquiring Person becoming
such or (ii) the date on which the Board of Directors of the Company declares an
Adverse Person to be such, the Board of Directors may cause the Company to
exchange the Rights (other than Rights owned by the Adverse Person or Acquiring
Person, as the case may be, which will have become null and void), in whole or
in part, at an exchange ratio of one share of Common Stock per Right (subject to
adjustment). Notwithstanding the foregoing, no such exchange may be effected at
any time after any Person becomes the beneficial owner of 50% or more of the
outstanding Common Stock.
The Rights Plan has certain anti-takeover effects including making it
prohibitively expensive for a raider to try to control or take over the Company
unilaterally and without negotiation with the Board of Directors. Although
intended to preserve for the stockholders the long term value of the Company,
the Rights Plan may make it more difficult for stockholders of the Company to
benefit from certain transactions which are opposed by the incumbent Board of
Directors.
ANTI-TAKEOVER PROVISIONS
In addition to the Rights Plan, the Articles of Incorporation and Bylaws of
the Company and Nevada law include certain provisions which may have the effect
of delaying or deterring a change in control or management of the Company or
encouraging persons considering unsolicited tender offers or other unilateral
takeover proposals to negotiate with the Board of Directors rather than pursue
non-negotiated takeover attempts. These provisions include a classified board of
directors, authorized blank check preferred stock, restrictions on business
combinations and the availability of authorized but unissued Common Stock. See
"-- Preferred Stock."
The Company's Bylaws contain provisions dividing the Board of Directors
into classes with only one class standing for election each year. A staggered
board makes it more difficult for stockholders to change the majority of the
directors and instead promotes a continuity of existing management.
Nevada's "Combinations with Interested Stockholders Statute," Nevada
Revised Statutes sec. 78.411-78.444, which applies to any Nevada corporation,
including the Company, subject to the reporting requirements of Section 12 of
the Exchange Act, prohibits an "interested stockholder" from entering into a
"combination" with the corporation for three years, unless certain conditions
are met. A "combination" includes (a) any merger with an "interested
stockholder," or any other corporation which is or after the merger would be, an
affiliate or associate of the interested stockholder, (b) any sale, lease,
exchange, mortgage, pledge, transfer or other disposition, in one transaction or
a series of transactions, to or with an "interested stockholder," having (i) an
aggregate market value equal to 5% or more of the aggregate market value of the
corporation's assets, (ii) an aggregate market value equal to 5% or more of the
aggregate market value of all outstanding shares of the corporation, or (iii)
representing 10% or more of the earning power or net income of the corporation,
(c) any issuance or transfer of shares of the corporation or its subsidiaries,
to the "interested stockholder," having an aggregate market value equal to 5% or
more of the aggregate market value of all of the outstanding shares of the
corporation, (d) the adoption of any plan or proposal for the liquidation or
dissolution of the corporation proposed by the "interested stockholder," (e)
certain transactions which would result in increasing the proportionate share of
shares of the corporation owned by the "interested stockholder," or (f) the
receipt of benefits by an "interested stockholder," except proportionately as a
stockholder, of any loans, advances or other financial benefits provided by the
corporation. An "interested stockholder" is a person who (i) directly or
indirectly owns 10% or more of the voting power of the outstanding voting shares
of the corporation or (ii) an affiliate or associate of the corporation which at
any time within three years before the date in question was the beneficial
owner, directly or indirectly, of 10% or more of the voting power of the then
outstanding shares of the corporation.
A corporation to which the statute applies may not engage in a
"combination" within three years after the interested stockholder acquired its
shares, unless the combination or the interested stockholder's acquisition of
shares was approved by the board of directors before the interested stockholder
acquired the shares. If this approval is not obtained, the combination may be
consummated after the three year period expires if either (a)(i) the board of
directors of the corporation approved, prior to such person becoming an
interested
45
<PAGE> 46
stockholder, the combination or the purchase of shares by the interested
stockholder or (ii) the combination is approved by the affirmative vote of
holders of a majority of voting power not beneficially owned by the interested
stockholder at a meeting called no earlier than three years after the date the
interested stockholder became such or (b) the aggregate amount of cash and the
market value of consideration other than cash to be received by holders of
common shares and holders of any other class or series of shares meets the
minimum requirements set forth in Section 78.441 through 78.443, inclusive, and
prior to the consummation of the combination, except in limited circumstances,
the "interested stockholder" would not have become the beneficial owner of
additional voting shares of the corporation.
In addition to the foregoing statute, Nevada has an "Acquisition of
Controlling Interest Statute," Nevada Revised Statute sec. 78.378-78.3793, which
prohibits an acquiror, under certain circumstances, from voting shares of a
target corporation's stock after crossing certain threshold ownership
percentages, unless the acquiror obtains the approval of the target
corporation's stockholders. The Control Share Acquisition Statute only applies
to Nevada corporations with at least 200 stockholders, including at least 100
record stockholders who are Nevada residents, and which do business directly or
indirectly in Nevada and whose Articles of Incorporation or Bylaws in effect 10
days following the acquisition of a controlling interest by an acquiror does not
prohibit its application. The Company does not intend to "do business" in Nevada
within the meaning of the Control Share Acquisition Statute. Therefore, the
Company believes it is unlikely that the Control Share Acquisition Statute will
apply to it. The statute specifies three thresholds: at least one-fifth but less
than one-third, at least one-third but less than a majority, and a majority or
more, of the outstanding voting power. Once an acquiror crosses one of the above
thresholds, shares which it acquired in the transaction taking it over the
threshold or within ninety days thereof become "Control Shares" which could be
deprived of the right to vote until a majority of the disinterested stockholders
restore that right. A special stockholders' meeting may be called at the request
of the acquiror to consider the voting rights of the acquiror's shares. If the
acquiror requests a special meeting, then the meeting must take place no earlier
than 30 days (unless the acquiror makes the meeting be held sooner) and no more
than 50 days (unless the acquiror agrees to a later date) after the delivery by
the acquiror to the corporation of an information statement which sets forth the
range of voting power that the acquiror has acquired or proposes to acquire and
certain other information concerning the acquiror and the proposed control share
acquisition. If no such request for a stockholders' meeting is made,
consideration of the voting rights of the acquiror's shares must be taken at the
next special or annual stockholders' meeting. If the stockholders fail to
restore voting rights to the acquiror, or if the acquiror fails to timely
deliver an information statement to the corporation, then the corporation may,
if so provided in its Articles or Bylaws, call certain of the acquiror's shares
for redemption at the average price paid for the control shares by the acquiror.
The Company's Articles and Bylaws do not currently permit it to call an
acquiror's shares for redemption under these circumstances. The Control Share
Acquisition Statute also provides that in the event the stockholders restore
full voting rights to a holder of Control Shares that owns a majority of the
voting stock, then all other stockholders who do not vote in favor of restoring
voting rights to the Control Shares may demand payment for the "fair value" of
their shares (which is generally equal to the highest price paid by the acquiror
in the transaction subjecting the acquiror to the statute.)
TRANSFER AGENT AND REGISTRAR
The Transfer Agent and Registrar for the Common Stock is American Stock
Transfer and Trust Company.
46
<PAGE> 47
UNDERWRITING
Upon the terms and subject to the conditions stated in the Underwriting
Agreement dated the date hereof, each Underwriter named below has severally
agreed to purchase, and the Company and the Selling Stockholders have agreed to
sell to such Underwriter, the number of shares of Common Stock set forth
opposite the name of such Underwriter.
<TABLE>
<CAPTION>
NUMBER
NAME OF SHARES
- ------------------------------------------- ---------
<S> <C>
Smith Barney Inc. ...................... 977,000
Raymond James & Associates, Inc. ....... 977,000
Bear, Stearns & Co. Inc. ............... 977,000
Oppenheimer & Co., Inc. ................ 977,000
Rodman & Renshaw, Inc. ................. 977,000
Gaines, Berland Inc. ................... 130,000
Jefferies & Company, Inc. .............. 130,000
<CAPTION>
NUMBER
NAME OF SHARES
- ------------------------------------------- ---------
<S> <C>
Johnson, Rice & Company L.L.C. ............. 130,000
Rauscher Pierce Refsnes, Inc. .............. 130,000
Roney & Co. ................................ 130,000
Southwest Securities, Inc. ................. 130,000
Wasserstein Perella Securities, Inc. ....... 130,000
---------
Total.............................. 5,795,000
=========
</TABLE>
The Underwriting Agreement provides that the obligations of the several
Underwriters to pay for and accept delivery of the shares are subject to
approval of certain legal matters by counsel and to certain other conditions.
The Underwriters are obligated to take and pay for all shares of Common Stock
offered hereby (other than those covered by the over-allotment option described
below) if any such shares are taken.
The Underwriters, for whom Smith Barney Inc., Raymond James & Associates,
Inc., Bear, Stearns & Co. Inc., Oppenheimer & Co., Inc. and Rodman & Renshaw,
Inc. are acting as the Representatives, propose to offer part of the shares
directly to the public at the public offering price set forth on the cover page
of this Prospectus and part of the shares to certain dealers at a price which
represents a concession not in excess of $0.37 per share under the public
offering price. The Underwriters may allow, and such dealers may reallow, a
concession not in excess of $0.10 per share to certain other dealers. After the
initial offering of the shares to the public, the public offering price and such
concessions may be changed by the Representatives.
The Company has granted to the Underwriters an option, exercisable for
thirty days from the date of this Prospectus, to purchase up to 869,250
additional shares of Common Stock at the price to the public set forth on the
cover page of this Prospectus minus the underwriting discounts and commissions.
The Underwriters may exercise such option solely for the purpose of covering
over-allotments, if any, in connection with the offering of the shares offered
hereby. To the extent such option is exercised, each Underwriter will be
obligated, subject to certain conditions, to purchase approximately the same
percentage of such additional shares as the number of shares set forth opposite
each Underwriter's name in the preceding table bears to the total number of
shares listed in such table.
The Company, its executive officers and directors, and the Selling
Stockholders have agreed that, for a period of 120 days from the date of this
Prospectus, they will not, without the prior written consent of Smith Barney
Inc., offer, sell, contract to sell, or otherwise dispose of, any shares of
Common Stock of the Company or any securities convertible into, or exercisable
or exchangeable for, Common Stock of the Company.
In connection with this Offering, certain Underwriters (and selling group
members) may engage in passive market-making transactions in the Common Stock on
the Nasdaq National Market in accordance with Rule 10b-6A under the Exchange
Act. Rule 10b-6A permits, upon the satisfaction of certain conditions,
underwriters and selling group members participating in a distribution that are
also Nasdaq market makers in the security being distributed to engage in limited
market making transactions during the period when Rule 10b-6 under the Exchange
Act would otherwise prohibit such activity. Rule 10b-6A generally prohibits
underwriters and selling group members engaged in passive market making from
entering a bid or effecting a purchase at a price that exceeds the highest bid
for those securities displayed on Nasdaq by a market maker that is not
participating in the distribution. Under Rule 10b-6A, each underwriter or
selling group member engaged in passive market making is subject to a daily net
purchase limitation equal to 30% of such entity's average daily trading volume
during the two full consecutive calendar months immediately preceding the date
of the filing of the registration statement under the Securities Act pertaining
to the security to be distributed.
47
<PAGE> 48
The Company, the Selling Stockholders and the Underwriters have agreed to
indemnify each other against certain liabilities, including liabilities under
the Securities Act.
LEGAL MATTERS
Certain legal matters in connection with the shares of Common Stock offered
hereby are being passed upon for the Company by Locke Purnell Rain Harrell (A
Professional Corporation), Dallas, Texas and for the Underwriters by Baker &
Botts, L.L.P., Dallas, Texas.
EXPERTS
The consolidated financial statements of Comstock Resources, Inc. and its
subsidiaries as of December 31, 1995, and for the three years in the period then
ended, included in this Prospectus, have been audited by Arthur Andersen LLP,
independent public accountants, as indicated in their report with respect
thereto, and are included herein in reliance upon the authority of said firm as
experts in giving said report.
The estimates as of December 31, 1993, 1994 and 1995, relating to the
Company's actual and pro forma proved oil and natural gas reserves, future net
revenues of oil and natural gas reserves and present value of future net
revenues of oil and natural gas reserves included or incorporated by reference
herein are based upon reports prepared by Lee Keeling and Associates, Inc. and
are included or incorporated by reference herein in reliance upon such reports
and upon the authority of such firm as experts in petroleum engineering.
48
<PAGE> 49
GLOSSARY
The following are abbreviations and definitions of terms commonly used in
the oil and gas industry and this Prospectus. Natural gas equivalents and crude
oil equivalents are determined using the ratio of six Mcf to one Bbl.
"BBL" means a barrel of 42 U.S. gallons of oil.
"BCF" means one billion cubic feet of natural gas.
"BCFE" means one billion cubic feet of natural gas equivalent.
"BTUS" means British thermal units, which is the heat required to raise the
temperature of a one-pound mass of water from 58.5 to 59.5 degrees
fahrenheit.
"COMPLETION" means the installation of permanent equipment for the production of
oil or gas.
"CONDENSATE" means a hydrocarbon mixture that becomes liquid and separates from
natural gas when the gas is produced and is similar to crude oil.
"DEVELOPMENT WELL" means a well drilled within the proved area of an oil or gas
reservoir to the depth of a stratigraphic horizon known to be productive.
"DRY HOLE" means a well found to be incapable of producing hydrocarbons in
sufficient quantities such that proceeds from the sale of such production
exceed production expenses and taxes.
"EXPLORATORY WELL" means a well drilled to find and produce oil or natural gas
reserves not classified as proved, to find a new productive reservoir in a
field previously found to be productive of oil or natural gas in another
reservoir or to extend a known reservoir.
"GROSS" when used with respect to acres or wells, production or reserves refers
to the total acres or wells in which the Company or other specified person
has a working interest.
"MBBLS" means one thousand barrels of oil.
"MCF" means one thousand cubic feet of natural gas.
"MCFE" means thousand cubic feet of natural gas equivalent.
"MMBBLS" means millions of barrels of oil.
"MMBTUS" means one million Btus.
"MMCF" means one million cubic feet of natural gas.
"MMCFE" means one million cubic feet of natural gas equivalent.
"NET" when used with respect to acres or wells, refers to gross acres of wells
multiplied, in each case, by the percentage working interest owned by the
Company.
"NET PRODUCTION" means production that is owned by the Company less royalties
and production due others.
"OIL" means crude oil or condensate.
"OPERATOR" means the individual or company responsible for the exploration,
development, and production of an oil or gas well or lease.
"PRESENT VALUE OF PROVED RESERVES" means the present value of estimated future
revenues to be generated from the production of proved reserves calculated
in accordance with Commission guidelines, net of estimated production and
future development costs, using prices and costs as of the date of
estimation without future escalation, without giving effect to non-property
related expenses such as general and administrative expenses, debt service,
future income tax expense and depreciation, depletion and amortization, and
discounted using an annual discount rate of 10%.
"PROVED DEVELOPED RESERVES" means reserves that can be expected to be recovered
through existing wells with existing equipment and operating methods.
Additional oil and gas expected to be obtained through the application of
fluid injection or other improved recovery techniques for supplementing the
natural forces and mechanisms of primary recovery will be included as
"proved developed reserves" only after testing by a pilot project or after
the operation of an installed program has confirmed through production
response that increased recovery will be achieved.
49
<PAGE> 50
"PROVED RESERVES" means the estimated quantities of crude oil, natural gas, and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known
reservoirs under existing economic and operating conditions, i.e., prices
and costs as of the date the estimate is made. Prices include consideration
of changes in existing prices provided only by contractual arrangements,
but not on escalations based upon future conditions.
(i) Reservoirs are considered proved if economic producibility is
supported by either actual production or conclusive formation tests. The
area of a reservoir considered proved includes (A) that portion delineated
by drilling and defined by gas-oil and/or oil-water contacts, if any; and
(B) the immediately adjoining portions not yet drilled, but which can be
reasonably judged as economically productive on the basis of available
geological and engineering data. In the absence of information on fluid
contacts, the lowest known structural occurrence of hydrocarbons controls
the lower proved limit of the reservoir.
(ii) Reserves which can be produced economically through application
of improved recovery techniques (such as fluid injection) are included in
the "proved" classification when successful testing by a pilot project, or
the operation of an installed program in the reservoir, provides support
for the engineering analysis on which the project or program was based.
(iii) Estimates of proved reserves do not include the following: (A)
oil that may become available from known reservoirs but is classified
separately as "indicated additional reserves"; (B) crude oil, natural gas,
and natural gas liquids, the recovery of which is subject to reasonable
doubt because of uncertainty as to geology, reservoir characteristics, or
economic factors; (C) crude oil, natural gas, and natural gas liquids, that
may occur in undrilled prospects; and (D) crude oil, natural gas, and
natural gas liquids, that may be recovered from oil shales, coal, gilsonite
and other such resources.
"PROVED UNDEVELOPED RESERVES" means reserves that are expected to be recovered
from new wells on undrilled acreage, or from existing wells where a
relatively major expenditure is required for recompletion. Reserves on
undrilled acreage shall be limited to those drilling units offsetting
productive units that are reasonably certain of production when drilled.
Proved reserves for other undrilled units can be claimed only where it can
be demonstrated with certainty that there is continuity of production from
the existing productive formation. Under no circumstances should estimates
for proved undeveloped reserves be attributable to any acreage for which an
application of fluid injection or other improved recovery technique is
contemplated, unless such techniques have been proved effective by actual
tests in the area and in the same reservoir.
"RECOMPLETION" means the completion for production of an existing well bore in
another formation from that in which the well has been previously
completed.
"RESERVES" means proved reserves.
"ROYALTY" means an interest in an oil and gas lease that gives the owner of the
interest the right to receive a portion of the production from the leased
acreage (or of the proceeds of the sale thereof), but generally does not
require the owner to pay any portion of the costs of drilling or operating
the wells on the leased acreage. Royalties may be either landowner's
royalties, which are reserved by the owner of the leased acreage at the
time the lease is granted, or overriding royalties, which are usually
reserved by an owner of the leasehold in connection with a transfer to a
subsequent owner.
"3-D SEISMIC" means an advanced technology method of detecting accumulations of
hydrocarbons identified by the collection and measurement of the intensity
and timing of sound waves transmitted into the earth as they reflect back
to the surface.
"WORKING INTEREST" means an interest in an oil and gas lease that gives the
owner of the interest the right to drill for and produce oil and gas on the
leased acreage and requires the owner to pay a share of the costs of
drilling and production operations. The share of production to which a
working interest owner is entitled will always be smaller than the share of
costs that the working interest owner is required to bear, with the balance
of the production accruing to the owners of royalties. For example, the
owner of a 100% working interest in an lease burdened only by a landowner's
royalty of 12.5% would be required to pay 100% of the costs of a well but
would be entitled to retain 87.5% of the production.
"WORKOVER" means operations on a producing well to restore or increase
production.
50
<PAGE> 51
AVAILABLE INFORMATION
The Company is subject to the informational requirements of the Securities
Exchange Act of 1934, as amended ("Exchange Act"), and in accordance therewith
files reports, proxy statements and other information with the Securities and
Exchange Commission (the "Commission"). Such reports, proxy statements and other
information filed by the Company with the Commission can be inspected and
copied, at the prescribed rates, at the public reference facilities of the
Commission at Room 1024, Judiciary Plaza, 450 Fifth Street, N.W., Washington,
D.C. 20549, and at the Commission's regional offices at 7 World Trade Center,
Suite 1300, New York, New York 10048, and Citicorp Center, 500 West Madison
Street, Suite 1400, Chicago, Illinois 60661. Copies of such material can also be
obtained from the Commission at prescribed rates by addressing written requests
to the Public Reference Section of the Commission at 450 Fifth Street, N.W.,
Washington, D.C. 20549. The Commission maintains a website (http://www.sec.gov)
which contains reports, proxy statements and other information regarding
registrants, including the Company, who file electronically with the Commission.
The Company's Common Stock is traded on the Nasdaq National Market. Reports,
proxy statements and other information concerning the Company may be inspected
at the National Association of Securities Dealers, Inc., 1735 K Street, N.W.,
Washington, D.C. 20006.
The Company has filed with the Commission a Registration Statement on Form
S-3 ("Registration Statement") under the Securities Act of 1933, as amended
("Securities Act"), with respect to the Common Stock offered hereby. This
Prospectus, which is a part of the Registration Statement, does not contain all
of the information as set forth in the Registration Statement and the exhibits
and schedules thereto, certain portions of which have been omitted as permitted
by the rules and regulations of the Commission. The Registration Statement may
be inspected, and copied at prescribed rates, at the Commission's public
reference facilities at Room 1024, Judiciary Plaza, 450 Fifth Street, N.W.,
Washington, D.C. 20549. Statements made in this Prospectus as to the contents of
any contract, agreement or other document referred to are not necessarily
complete. With respect to each contract, agreement or other document, reference
is made to the copy of such document filed as an exhibit to the Registration
Statement or otherwise filed with the Commission. Each such statement is
qualified in its entirety by such reference.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The following documents filed by the Company with the Commission are hereby
incorporated by reference into this Prospectus:
(1) Annual Report on Form 10-K for the year ended December 31, 1995;
(2) Quarterly Reports on Form 10-Q for the quarters ended March 31,
1996, June 30, 1996, and September 30, 1996;
(3) Current Report on Form 8-K dated May 1, 1996; and
(4) the description of the Company's Common Stock contained in the
Company's Registration Statement on Form 8-A, effective as of December 14,
1990, including any amendment filed for the purpose of updating such
information.
All documents filed by the Company pursuant to Sections 13(a), 13(c), 14 or
15(d) of the Exchange Act subsequent to the date of this Prospectus and prior to
the termination of the offering made hereby shall be deemed to be incorporated
by reference in this Prospectus and to be a part hereof from the respective
dates of the filing of such documents. See "Available Information." Any
statement or information contained in a document incorporated or deemed to be
incorporated herein by reference shall be deemed modified or superseded for
purposes of this Prospectus to the extent that a statement contained herein or
in any other subsequently filed document which also is or is deemed to be
incorporated by reference herein modifies or supersedes such statement. Any such
statement so modified or superseded shall not be deemed, except as so modified
or superseded, to constitute a part of this Prospectus.
The Company will provide without charge to any person to whom this
Prospectus is delivered, upon written or oral request, a copy of any or all of
the documents incorporated herein by reference (other than exhibits to such
documents not specifically incorporated by reference). Requests should be
directed to Comstock Resources, Inc., 5005 LBJ Freeway, Suite 1000, Dallas,
Texas 75244, (972) 701-2000, Attention: Secretary.
51
<PAGE> 52
INDEX TO FINANCIAL STATEMENTS
CONSOLIDATED FINANCIAL STATEMENTS OF
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
<TABLE>
<S> <C>
Report of Independent Public Accountants............................................. F-2
Consolidated Balance Sheets as of December 31, 1994 and 1995......................... F-3
Consolidated Statements of Operations for the Years Ended December 31, 1993, 1994 and
1995............................................................................... F-4
Consolidated Statements of Stockholders' Equity for the Years Ended December 31,
1993, 1994 and 1995................................................................ F-5
Consolidated Statements of Cash Flows for the Years Ended December 31, 1993, 1994 and
1995............................................................................... F-6
Notes to Consolidated Financial Statements........................................... F-7
Consolidated Balance Sheets as of December 31, 1995 and September 30, 1996........... F-21
Consolidated Statements of Operations for the Nine Months ended September 30, 1995
and 1996........................................................................... F-22
Consolidated Statement of Stockholders' Equity for the Nine Months Ended
September 30, 1996................................................................. F-23
Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 1995
and 1996........................................................................... F-24
Notes to Consolidated Financial Statements........................................... F-25
</TABLE>
F-1
<PAGE> 53
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Board of Directors and Stockholders
of Comstock Resources, Inc.:
We have audited the accompanying consolidated balance sheets of Comstock
Resources, Inc. (a Nevada corporation) and subsidiaries as of December 31, 1994
and 1995, and the related consolidated statements of operations, stockholders'
equity and cash flows for each of the three years in the period ended December
31, 1995. 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 assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above present fairly,
in all material respects, the financial position of Comstock Resources, Inc. and
subsidiaries as of December 31, 1994 and 1995, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1995, in conformity with generally accepted accounting principles.
As discussed in Note 2 to the financial statements, the Company changed its
method of accounting for the impairment of long-lived assets in the fourth
quarter of 1995.
ARTHUR ANDERSEN LLP
Dallas, Texas,
March 4, 1996
F-2
<PAGE> 54
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
AS OF DECEMBER 31, 1994 AND 1995
ASSETS
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------
1994 1995
-------- --------
(IN THOUSANDS)
<S> <C> <C>
Cash and Cash Equivalents.............................................. $ 3,425 $ 1,917
Accounts Receivable:
Oil and gas sales.................................................... 2,616 5,385
Gas marketing sales.................................................. 5,559 8,451
Joint interest operations............................................ 619 1,230
Other Current Assets................................................... 344 264
-------- --------
Total current assets......................................... 12,563 17,247
Property and Equipment:
Oil and gas properties, successful efforts method.................... 113,269 154,844
Other................................................................ 1,372 2,717
Accumulated depreciation, depletion and amortization................. (36,652) (55,445)
-------- --------
Net property and equipment................................... 77,989 102,116
Other Assets........................................................... 1,019 736
-------- --------
$ 91,571 $120,099
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Portion of Long-term Debt...................................... $ 7,010 $ 18,677
Accounts Payable and Accrued Expenses.................................. 11,489 16,511
-------- --------
Total current liabilities.................................... 18,499 35,188
Long-term Debt, less current portion................................... 30,922 53,134
Deferred Revenue....................................................... -- 430
Other Noncurrent Liabilities........................................... 945 1,219
Stockholders' Equity:
Preferred stock -- $10.00 par, 5,000,000 shares authorized, 1,600,000
and 3,100,000 shares outstanding at December 31, 1994 and 1995,
respectively...................................................... 16,000 31,000
Common stock -- $0.50 par, 30,000,000 shares authorized, 12,342,811
and 12,926,672 shares outstanding at December 31, 1994 and 1995,
respectively...................................................... 6,171 6,463
Additional paid-in capital........................................... 36,524 38,183
Retained deficit..................................................... (17,375) (45,444)
Less: Deferred compensation -- restricted stock grants............... (115) (74)
-------- --------
Total stockholders' equity................................... 41,205 30,128
-------- --------
$ 91,571 $120,099
======== ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-3
<PAGE> 55
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
FOR THE YEARS ENDED DECEMBER 31, 1993, 1994 AND 1995
<TABLE>
<CAPTION>
1993 1994 1995
------- ------- --------
(IN THOUSANDS, EXCEPT
PER SHARE AMOUNTS)
<S> <C> <C> <C>
Revenues:
Oil and gas sales.......................................... $21,805 $16,855 $ 22,091
Gas marketing sales........................................ -- 14,957 50,078
Gas gathering and processing............................... 107 72 600
Gain on sales of property.................................. 111 328 2,608
Other income............................................... 430 442 291
------- ------- --------
Total revenues..................................... 22,453 32,654 75,668
------- ------- --------
Expenses:
Oil and gas operating...................................... 6,673 6,099 7,427
Natural gas purchases...................................... -- 14,521 48,909
Gas gathering and processing............................... 91 11 209
Exploration................................................ 423 -- --
Depreciation, depletion and amortization................... 8,334 7,390 8,613
General and administrative, net............................ 1,834 1,823 1,979
Interest................................................... 2,184 2,869 5,542
Impairment of oil and gas properties....................... -- -- 29,150
------- ------- --------
Total expenses..................................... 19,539 32,713 101,829
------- ------- --------
Income (loss) before income taxes and extraordinary item..... 2,914 (59) (26,161)
Provision for income taxes................................... -- -- --
------- ------- --------
Net Income (loss) before extraordinary item.................. 2,914 (59) (26,161)
Preferred stock dividends.................................... (173) (818) (1,908)
------- ------- --------
Net income (loss) attributable to common stock before
extraordinary item......................................... 2,741 (877) (28,069)
Extraordinary item -- loss on early extinguishment of debt... (417) (615) --
------- ------- --------
Net income (loss) attributable to common stock after
extraordinary item......................................... $ 2,324 $(1,492) $(28,069)
======= ======= ========
Net income (loss) per share:
Before extraordinary item.................................. $ .25 $ (.07) $ (2.24)
Extraordinary item......................................... (.03) (.05) --
------- ------- --------
After extraordinary item................................... $ .22 $ (.12) $ (2.24)
======= ======= ========
Weighted average number of common and common stock
equivalent shares outstanding.............................. 10,762 12,065 12,546
======= ======= ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-4
<PAGE> 56
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
FOR THE YEARS ENDED DECEMBER 31, 1993, 1994 AND 1995
<TABLE>
<CAPTION>
DEFERRED
ADDITIONAL RETAINED COMPENSATION--
PREFERRED COMMON PAID-IN EARNINGS RESTRICTED
STOCK STOCK CAPITAL (DEFICIT) STOCK GRANTS TOTAL
--------- ------ ---------- -------- -------------- --------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Balance at December 31, 1992...... $ 1,500 $4,930 $ 34,027 $(17,056) $ (292) $ 23,109
Conversion of preferred stock... (1,500) 428 1,072 -- -- --
Issuance of common stock........ -- 541 2,773 -- -- 3,314
Restricted stock grants......... -- (30 ) (56) -- 136 50
Net income attributable to
common stock................. -- -- -- 2,324 -- 2,324
Distributions................... -- -- -- (1,151) -- (1,151)
-------- ------ -------- -------- ------ --------
Balance at December 31, 1993...... -- 5,869 37,816 (15,883) (156) 27,646
-------- ------ -------- -------- ------ --------
Issuance of preferred stock..... 16,000 -- (2,000) -- -- 14,000
Issuance of common stock........ -- 302 708 -- -- 1,010
Restricted stock grants......... -- -- -- -- 41 41
Net loss attributable to common
stock........................ -- -- -- (1,492) -- (1,492)
-------- ------ -------- -------- ------ --------
Balance at December 31, 1994...... 16,000 6,171 36,524 (17,375) (115) 41,205
-------- ------ -------- -------- ------ --------
Issuance of preferred stock..... 15,000 -- -- -- -- 15,000
Issuance of common stock........ -- 292 1,659 -- -- 1,951
Restricted stock grants......... -- -- -- -- 41 41
Net loss attributable to common
stock........................ -- -- -- (28,069) -- (28,069)
-------- ------ -------- -------- ------ --------
Balance at December 31, 1995...... $ 31,000 $6,463 $ 38,183 $(45,444) $ (74) $ 30,128
======== ====== ======== ======== ====== ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-5
<PAGE> 57
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE YEARS ENDED DECEMBER 31, 1993, 1994 AND 1995
<TABLE>
<CAPTION>
1993 1994 1995
-------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Cash flows from operating activities:
Net Income (loss) before extraordinary item.............. $ 2,914 $ (59) $(26,161)
Adjustments to reconcile income (loss) before
extraordinary item to net cash provided by operating
activities:
Compensation paid in common stock..................... 49 154 154
Depreciation, depletion and amortization.............. 8,334 7,390 8,613
Impairment of oil and gas properties.................. -- -- 29,150
Deferred revenue...................................... (1,602) (561) 430
Amortization of discounts............................. 334 174 --
Exploration........................................... 423 -- --
Gain on sales of property............................. (112) (328) (2,608)
Bad debt expense...................................... -- 80 --
-------- -------- --------
Working capital provided by operations................... 10,340 6,850 9,578
Decrease (increase) in accounts receivable............ 3,970 (3,288) (6,272)
Decrease (increase) in prepaid expenses and other..... (74) 107 79
Increase in accounts payable and accrued expenses..... 2,252 3,707 5,022
-------- -------- --------
Net cash provided by operating activities................ 16,488 7,376 8,407
-------- -------- --------
Cash flows from investing activities:
Proceeds from sales of properties........................ 691 396 3,085
Collections of notes receivable.......................... 792 167 --
Capital expenditures and acquisitions.................... (18,637) (16,386) (61,809)
Repurchase of volumetric production payment.............. -- (8,149) --
Purchase of other assets................................. (261) -- --
-------- -------- --------
Net cash used for investing activities................... (17,415) (23,972) (58,724)
-------- -------- --------
Cash flows from financing activities:
Borrowings............................................... 33,431 34,880 58,404
Proceeds from preferred stock issuances.................. -- 6,000 15,000
Proceeds from common stock issuances..................... -- 215 25
Principal payments on debt............................... (30,381) (21,497) (24,525)
Financing costs.......................................... (806) -- --
Stock issuance costs..................................... (129) (332) (95)
Distributions............................................ (1,152) -- --
Dividends on preferred stock............................. (173) -- --
-------- -------- --------
Net cash provided by financing activities................ 790 19,266 48,809
-------- -------- --------
Net increase (decrease) in cash and cash equivalents..... (137) 2,670 (1,508)
Cash and cash equivalents, beginning of year............. 892 755 3,425
-------- -------- --------
Cash and cash equivalents, end of year................... $ 755 $ 3,425 $ 1,917
======== ======== ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-6
<PAGE> 58
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) BUSINESS AND ORGANIZATION
Comstock Resources, Inc., a Nevada corporation (together with its
subsidiaries, the "Company"), was formed in 1919 as Comstock Tunnel and Drainage
Company. In 1987, the Company's name was changed to Comstock Resources, Inc. The
Company is primarily engaged in the acquisition, development and production of
oil and natural gas reserves in the United States. The Company is also engaged
in the purchase, gathering, processing and marketing of natural gas.
(2) SIGNIFICANT ACCOUNTING POLICIES
BASIS OF PRESENTATION
On November 10, 1993, the Company, Stanford Offshore Energy, Inc.
("Stanford") and all of the stockholders of Stanford entered into an Agreement
and Plan of Reorganization (the "Merger Agreement") providing for the
acquisition of all outstanding stock of Stanford by the Company in exchange for
1,760,000 shares of common stock of the Company. Pursuant to the merger,
effective November 17, 1993, Stanford became a wholly owned subsidiary of the
Company, and now operates under the name Comstock Offshore Energy, Inc.
The merger of Stanford and the Company was accounted for using the pooling
of interests method. Accordingly, the accompanying financial statements of the
Company include the accounts and operations of Stanford since Stanford's
inception on August 31, 1992.
PRINCIPLES OF CONSOLIDATION
The consolidated financial statements include the accounts of the Company
and its wholly owned subsidiaries. In addition, the Company's interests in
certain partnerships and joint ventures have been proportionately consolidated,
whereby the Company's proportionate share of each partnership or joint venture's
assets, liabilities, revenues and expenses is included in the appropriate
accounts in the consolidated financial statements. All significant intercompany
accounts and transactions have been eliminated in consolidation.
USE OF ESTIMATES
The preparation of financial statements in conformity with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the 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.
CONCENTRATIONS OF CREDIT RISK
Although the Company's cash equivalents, accounts receivable and derivative
financial instruments are exposed to credit loss, the Company does not believe
such risk to be significant. Cash equivalents are high-grade, short-term
securities, placed with highly rated financial institutions. Most of the
Company's accounts receivable are from a broad and diverse group of oil and gas
companies and, accordingly, do not represent a significant credit risk. The
Company's gas marketing activities generate accounts receivable from customers
including pipeline companies, local distribution companies and other gas
marketing companies. Letters of credit are obtained as considered necessary to
limit risk of loss.
F-7
<PAGE> 59
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
OIL AND GAS PROPERTIES
The Company follows the successful efforts method of accounting for its oil
and gas operations. Under this method, costs of productive wells, development
dry holes and productive leases are capitalized and amortized on a
unit-of-production basis over the life of the remaining related oil and gas
reserves. Cost centers for amortization purposes are determined on a
field-by-field basis. The estimated future costs of dismantlement, restoration
and abandonment are accrued as part of depreciation, depletion and amortization
expense.
Oil and gas leasehold costs are capitalized. Unproved oil and gas
properties with significant acquisition costs are periodically assessed and any
impairment in value is charged to expense. The costs of unproved properties
which are determined to be productive are transferred to proved oil and gas
properties.
Exploratory expenses, including geological and geophysical expenses and
delay rentals for oil and gas leases, are charged to expense as incurred.
Exploratory drilling costs are initially capitalized as unproved property but
charged to expense if and when the well is determined not to have found proved
oil and gas reserves.
Prior to the fourth quarter of 1995, the Company periodically reviewed the
carrying value of its proved oil and gas properties for impairment in value on a
company-wide basis by comparing the capitalized costs of proved oil and gas
properties with the undiscounted future cash flows after income taxes
attributable to proved oil and gas properties. Under this policy, no impairment
in carrying value was required during 1993 or 1994. In the fourth quarter of
1995, the Company adopted the Statement of Financial Accounting Standards No.
121 ("SFAS 121") "Accounting for the Impairment of Long-Lived Assets and
Long-Lived Assets to be Disposed of." SFAS 121 requires the Company to assess
the need for an impairment of capitalized costs of oil and gas properties on a
property by property basis. If an impairment is indicated based on undiscounted
expected future cash flows, then an impairment is recognized to the extent that
net capitalized costs exceed discounted expected future cash flows. In
connection with the adoption of SFAS 121, the Company provided an impairment of
$29,150,000 in 1995.
OTHER PROPERTY AND EQUIPMENT
Other property and equipment of the Company consists primarily of gas
gathering systems, a gas processing plant, trucks, well service equipment,
computer equipment, and furniture and fixtures which are depreciated over
estimated useful lives on a straight-line basis.
INCOME TAXES
Deferred income taxes are provided to reflect the future tax consequences
of differences between the tax basis of assets and liabilities and their
reported amounts in the financial statements using enacted tax rates.
EARNINGS PER SHARE
Net income (loss) attributable to common stock represents net income (loss)
less preferred stock dividend requirements of $173,000, $818,000 and $1,908,000
in 1993, 1994 and 1995, respectively. Net income (loss) attributable to common
stock per share is computed by dividing net income (loss) attributable to common
stock by the weighted average number of shares of common stock and common stock
equivalents outstanding during each period. Common stock equivalents include,
when applicable, dilutive stock options and warrants using the treasury stock
method.
STATEMENTS OF CASH FLOWS
For the purpose of the consolidated statements of cash flows, the Company
considers all highly liquid investments purchased with an original maturity of
three months or less to be cash equivalents.
F-8
<PAGE> 60
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following is a summary of all significant noncash investing and
financing activities:
<TABLE>
<CAPTION>
FOR THE YEAR ENDED
DECEMBER 31,
----------------------------
1993 1994 1995
------ ------ ------
(IN THOUSANDS)
<S> <C> <C> <C>
Common stock issued in payment of preferred stock
dividends.............................................. $ -- $ 818 $1,908
Common stock issued for compensation..................... -- 113 113
Preferred stock issued to repurchase volumetric
production payment..................................... -- 8,000 --
Common stock issued for acquisitions..................... 3,142 -- --
Common stock issued in settlement of note payable........ 301 -- --
</TABLE>
The Company made cash payments for interest of $2,067,000, $2,600,000 and
$5,836,000 in 1993, 1994 and 1995, respectively. The Company did not make any
cash payments for income taxes in any of the three years in the period ended
December 31, 1995.
(3) SIGNIFICANT ACQUISITIONS OF OIL AND GAS PROPERTIES
On June 8, 1994, the Company acquired interests in 5 producing gas wells
and the related oil and gas leases covering 2,048 acres in South Texas for $7.3
million.
On September 30, 1994, the Company repaid all indebtedness owed to, and
acquired certain property interests from MG Trade Finance Corp. The Company
acquired the net profits and overriding royalty interests owned by MG Trade
Finance Corp. in certain of the Company's oil and gas properties for $800,000.
On December 23, 1994, the Company acquired interests in 23 wells in South
Texas for $5.0 million and interests in a gas gathering system and gas
processing plant for approximately $440,000.
On May 15, 1995, the Company purchased interests in 14 producing offshore
oil and gas properties located in Louisiana state waters in the Gulf of Mexico
for $8.2 million.
On July 31, 1995, the Company purchased interests in certain producing oil
and gas properties and natural gas gathering systems located in East Texas and
North Louisiana for cash of $50.6 million. The Company acquired interests in 319
(188 net) oil and gas wells for $49.1 million and interests in gas gathering
systems for $1.5 million.
During 1995, the Company acquired interests in the Lake LaRose field in
South Louisiana for approximately $1.0 million.
F-9
<PAGE> 61
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The 1995 acquisitions were accounted for utilizing the purchase method of
accounting. The accompanying consolidated statements of operations include the
results of operations from the acquired properties beginning on the dates that
the acquisitions were closed. The following table summarizes the unaudited pro
forma effect on the Company's consolidated statements of operations for the year
ended December 31, 1995 as if the acquisitions consummated in 1995 had been
closed on January 1, 1994 and 1995. Future results may differ substantially from
pro forma results due to changes in prices received for oil and gas sold,
production declines and other factors. Therefore, the pro forma amounts should
not be considered indicative of future operations.
<TABLE>
<CAPTION>
1994 1995
PRO FORMA PRO FORMA
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Revenues....................................................... $52,214 $ 84,349
======= ========
Net income (loss) attributable to common stock before
extraordinary item........................................... 3,480 (28,345)
======= ========
Net income (loss) attributable to common stock after
extraordinary item........................................... 2,864 (28,345)
======= ========
Net income (loss) per share before extraordinary item.......... .29 (2.26)
======= ========
Net income (loss) per share after extraordinary item........... .24 (2.26)
======= ========
</TABLE>
(4) REPURCHASE OF PRODUCTION PAYMENTS
On July 22, 1994, the Company exchanged one million shares of newly issued
preferred stock, with a par value of $10.0 million and an estimated market value
of $8.0 million, and $10,150,000 in cash to repurchase certain production
payments previously conveyed by the Company to a major natural gas company in
November 1991. (See Note 9 for further discussion of the preferred stock.) The
exchange was effective April 1, 1994. The Company had a remaining obligation to
deliver 10.7 billion cubic feet of natural gas under a volumetric production
payment and had an obligation to repay $2.5 million under a monetary based
production payment. The consideration paid to acquire the natural gas reserves
subject to the volumetric production payment exceeded the deferred revenue
associated with the original sale of the volumetric production payment by
approximately $3.0 million. This amount was capitalized as oil and gas
properties in the accompanying financial statements.
F-10
<PAGE> 62
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(5) OIL AND GAS PRODUCING ACTIVITIES
Set forth below is certain information regarding the aggregate capitalized
costs of oil and gas properties and costs incurred in oil and gas property
acquisition, development and exploration activities:
CAPITALIZED COSTS
<TABLE>
<CAPTION>
DECEMBER 31,
---------------------
1994 1995
-------- --------
(IN THOUSANDS)
<S> <C> <C>
Proved properties.............................................. $113,269 $154,844
Accumulated depreciation, depletion and amortization........... (36,427) (55,183)
-------- --------
$ 76,842 $ 99,661
======== ========
</TABLE>
COSTS INCURRED
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
-------------------------------
1993 1994 1995
------- ------- -------
(IN THOUSANDS)
<S> <C> <C> <C>
Property acquisitions:
Proved properties................................... $18,604 $13,576 $56,093
Unproved properties................................. 247 -- --
Development costs..................................... 2,390 1,490 3,666
Exploration costs..................................... 423 -- --
------- ------- -------
$21,664 $15,066 $59,759
======= ======= =======
</TABLE>
The following presents the results of operations of oil and gas producing
activities for the three years in the period ended December 31, 1995:
<TABLE>
<CAPTION>
1993 1994 1995
------- ------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Oil and gas sales.................................... $21,805 $16,855 $ 22,091
Production costs..................................... (6,673) (6,099) (7,427)
Depreciation, depletion and amortization............. (7,953) (7,149) (8,277)
Impairment of oil and gas properties................. -- -- (29,150)
------- ------- --------
Operating income (loss).............................. 7,179 3,607 (22,763)
Income tax expense................................... -- -- --
------- ------- --------
Results of operations (excluding general and
administrative and interest expense)............... $ 7,179 $ 3,607 $(22,763)
======= ======= ========
</TABLE>
(6) GAS GATHERING, PROCESSING AND MARKETING ACTIVITIES
On June 10, 1994, the Company acquired the operations of a gas marketing
company for $70,000 and began marketing natural gas for third parties as well as
marketing the Company's own natural gas production. In September 1994, the
Company acquired the gas marketing operations and certain pipeline assets of a
privately held natural gas company for a purchase price of $1.1 million. The
Company paid $600,000 in cash and agreed to pay 35% of the gross margin from the
acquired gas marketing operations until the earlier of the time that the seller
has received an aggregate of $500,000 or September 30, 1997.
F-11
<PAGE> 63
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
On July 31, 1995, the Company acquired the managing general partner
interest and a 20.31% limited partner interest in Crosstex Pipeline Partners,
Ltd. ("Crosstex") for $1.4 million. The Company also acquired a 15 mile gas
gathering system in East Texas for $100,000. Crosstex owns 5 gas gathering
systems consisting of 63 miles in East Texas.
On August 1, 1995, the Company sold its 43.25% interest in the Wharton gas
processing plant and gathering system in Wharton County, Texas, which it
acquired in December 1994, to a third party for $3.0 million. A gain of $2.6
million related to the sale is reflected in the accompanying statement of
operations in 1995.
In September 1995, Comstock acquired a 40% interest in a gas processing
plant and related facilities in Harrison County, Texas for approximately
$500,000.
(7) LONG-TERM DEBT
Total debt at December 31, 1994 and 1995 consists of the following:
<TABLE>
<CAPTION>
1994 1995
------- --------
(IN THOUSANDS)
<S> <C> <C>
Bank term note.................................................. $ -- $ 10,000
Bank credit facility............................................ 37,580 61,590
12% subordinated notes.......................................... 319 206
Capital lease obligations....................................... 33 15
------- --------
37,932 71,811
Less current portion............................................ (7,010) (18,677)
------- --------
$30,922 $ 53,134
======= ========
</TABLE>
On December 31, 1995, the Company had $61,590,000 outstanding under a $100
million five-year revolving credit agreement with two banks. Amounts outstanding
under the credit facility bear interest at the agent bank's prime rate plus
1 1/2% (10% at December 31, 1995) and cannot exceed a borrowing base determined
semiannually by the banks. The borrowing base was $65,760,000 at December 31,
1995 and reduces by $1,060,000 each month beginning January 1, 1996 until the
next redetermination.
The Company also had $10.0 million outstanding under a one-year term note
which matures on July 31, 1996. Amounts outstanding under the term note bear
interest at the agent bank's prime rate plus 4% (12 1/2% at December 31, 1995).
Aggregate maturities of long-term debt for the five years ending December
31, are as follows:
<TABLE>
<CAPTION>
(IN THOUSANDS)
<S> <C>
1996........................................................... $ 18,677
1997........................................................... 12,814
1998........................................................... 40,320
1999........................................................... --
2000........................................................... --
--------
$ 71,811
========
</TABLE>
F-12
<PAGE> 64
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(8) LEASE COMMITMENTS
The Company rents office space under certain noncancellable leases and also
leases data processing time under a noncancellable lease. Minimum future
payments under the leases are as follows:
<TABLE>
<S> <C>
1996.................................................................. $269
1997.................................................................. 258
1998.................................................................. 236
1999.................................................................. 177
2000.................................................................. --
</TABLE>
(9) STOCKHOLDERS' EQUITY
COMMON STOCK
During 1993 the Company issued 950,921 shares of its common stock valued at
$3.1 million in connection with certain acquisitions of oil and gas properties.
In September 1993 the Company issued 120,500 shares valued at $301,000 in
settlement of amounts outstanding, including accrued interest, under a 10% note
payable to a former officer of the Company.
In January 1994 the Company issued 37,667 shares of its common stock to
four of its non-employee directors in payment of directors fees for 1994
aggregating $71,000, and for amounts due two non-employee directors for
consulting services in 1994 aggregating $42,000. During 1994 the Company issued
310,298 shares of its common stock to holders of its preferred stock in payment
of dividends on the preferred stock for 1994 aggregating $818,000.
In May 1995 the Company issued 27,815 shares of its common stock to four of
its non-employee directors in payment of directors fees for 1995 aggregating
$71,000, and for amounts due two non-employee directors for consulting services
in 1995 aggregating $42,000. During 1995 the Company issued 546,046 shares of
its common stock to holders of its preferred stock in payment of dividends on
the preferred stock for 1995 aggregating $1,908,000.
PREFERRED STOCK
On December 31, 1993, the holder of 150,000 shares of the Company's 1992
Series Cumulative Convertible Preferred Stock (the "Series 1992 Preferred"),
converted all of the Series 1992 Preferred into 857,143 shares of common stock
of the Company. As a result of the conversion, the Series 1992 Preferred
designation was retired.
On January 7, 1994, the Company sold 600,000 shares of its Series 1994
Convertible Preferred Stock, $10 par value per share (the "Series 1994
Preferred"), in a private placement for $6.0 million. The Series 1994 Preferred
bears quarterly dividends at the rate of $0.225 on each outstanding share (9%
per annum of the par value). Dividends are payable quarterly in cash or shares
of common stock, at the election of the Company. On January 1, 1999, and on each
January 1 thereafter, so long as any shares of the Series 1994 Preferred are
outstanding, the Company is obligated to redeem 120,000 shares of the Series
1994 Preferred at $10.00 per share plus accrued and unpaid dividends. At the
option of the Company, the mandatory redemption price may be paid either in cash
or in shares of common stock of the Company. The holders of the Series 1994
Preferred have the option to convert all or any part of such shares into shares
of common stock of the Company at any time at the initial conversion price of
$4.00 per share of common stock, subject to adjustment. The Company has the
option to redeem the shares of Series 1994 Preferred prior to January 1, 1999
after providing the holders of the Series 1994 Preferred a specified rate of
return on the initial purchase.
On July 22, 1994, the Company issued 1,000,000 shares of its 1994 Series B
Convertible Preferred Stock, $10 par value per share (the "1994 Series B
Preferred"), in connection with the repurchase of certain
F-13
<PAGE> 65
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
production payments previously conveyed by the Company to a major natural gas
company. The 1994 Series B Preferred bears quarterly dividends at the rate of
$0.15625 on each outstanding share (6.25% per annum of the par value). Dividends
are payable quarterly in cash, additional shares of 1994 Series B Preferred or
shares of common stock, at the election of the Company; provided, that if the
Company elects to pay a dividend in shares of stock, the holders of the 1994
Series B Preferred shall have the option to receive shares of common stock or
additional shares of 1994 Series B Preferred. The holders of the 1994 Series B
Preferred have the option to convert all or any part of such shares into shares
of common stock of the Company at any time at the initial conversion price of
$5.00 per share of common stock, subject to adjustment. The Company has the
option to redeem the shares of 1994 Series B Preferred at a rate of $14.00 per
share plus an additional 7 1/2% of the par value per annum compounded monthly
from the date of issuance. There is no mandatory redemption required on the 1994
Series B Preferred.
On June 19, 1995, the Company sold 1,500,000 shares of its Series 1995
Convertible Preferred Stock, $10 par value per share (the "Series 1995
Preferred"), in a private placement for $15.0 million. The Series 1995 Preferred
bears quarterly dividends at the rate of $0.225 on each outstanding share (9%
per annum of the par value). Dividends are payable quarterly in cash or shares
of the Company's common stock, at the election of the Company. On June 30, 2000
and on each June 30, thereafter, so long as any shares of the Series 1995
Preferred are outstanding, the Company is obligated to redeem 300,000 shares of
the Series 1995 Preferred at $10.00 per share plus accrued and unpaid dividends.
The mandatory redemption price may be paid either in cash or in shares of common
stock, at the option of the Company. The holders of the Series 1995 Preferred
have the option to convert all or any part of such shares into shares of common
stock of the Company at any time at the initial conversion price of $5.25 per
share of common stock, subject to adjustment. The Company has the option to
redeem the shares of Series 1995 Preferred after providing the holders of the
Series 1995 Preferred a specified rate of return on the initial purchase.
STOCK OPTIONS AND WARRANTS
On July 16, 1991, the Company's stockholders approved the 1991 Long-Term
Incentive Plan (the "Incentive Plan") for the Company's management including
officers, directors and managerial employees. The Incentive Plan authorizes the
grant of non-qualified stock options and incentive stock options and the grant
of restricted stock to key executives of the Company. As of December 31, 1995,
the Incentive Plan provided for future awards of stock options or restricted
stock grants of up to 529,000 shares of common stock plus 10% of any future
issuances of common stock.
F-14
<PAGE> 66
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Non-qualified stock options awarded under the Incentive Plan are summarized
below:
<TABLE>
<CAPTION>
EXERCISE PRICE
-------------------------
$2.00 $2.50 $3.00
----- ----- -----
(IN THOUSANDS)
<S> <C> <C> <C>
Outstanding at December 31, 1992............................... 625 -- --
Granted in 1993................................................ -- 196 85
Exercised in 1993.............................................. (20) (17) --
Forfeited in 1993.............................................. (80) -- --
--- --- ---
Outstanding at December 31, 1993............................... 525 179 85
--- --- ---
Exercised in 1994.............................................. -- (21) (15)
Forfeited in 1994.............................................. -- (49) --
--- --- ---
Outstanding at December 31, 1994............................... 525 109 70
--- --- ---
Granted in 1995................................................ -- -- 98
Exercised in 1995.............................................. -- (10) --
--- --- ---
Outstanding at December 31, 1994............................... 525 99 168
=== === ===
Exercisable at December 31, 1995............................... 387 84 168
=== === ===
</TABLE>
The Company also has stock purchase warrants outstanding that were issued
in connection with oil and gas property acquisitions and certain other
transactions. In addition, the Company has stock purchase options outstanding
issued to a former officer of the Company. The following table summarizes stock
purchase warrants and options outstanding at December 31, 1995, other than those
issued under the Incentive Plan:
<TABLE>
<CAPTION>
NUMBER
NUMBER OF SHARES EXERCISE
OF SHARES EXERCISABLE PRICE EXPIRATION DATE
- --------- ----------- -------- ---------------
(IN THOUSANDS)
<S> <C> <C> <C>
135 135 $ 5.75 June 1997
200 200 2.75 March 1998
200 200 3.00 March 1998
150 100 2.25 March 1998
218 218 5.00 October 1999
62 62 5.00 November 1999
224 224 5.00 December 1999
----- -----
1,189 1,139
===== =====
</TABLE>
RESTRICTED STOCK GRANTS
Under the Incentive Plan, officers and managerial employees of the Company
may be granted a right to receive shares of the Company's common stock without
cost to the employee. The shares vest over a ten-year period with credit given
for past service rendered to the Company.
F-15
<PAGE> 67
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
The following is a summary of shares of restricted common stock awarded
under the Incentive Plan:
<TABLE>
<CAPTION>
1993 1994 1995
--- --- ---
(IN THOUSANDS)
<S> <C> <C> <C>
Outstanding at beginning of year............................. 390 330 330
Cancelled or expired......................................... (60) -- --
--- --- ---
Outstanding at end of year................................... 330 330 330
=== === ===
Vested shares................................................ 195 225 255
=== === ===
</TABLE>
A provision for the restricted stock grants is made ratably over the
vesting period. Compensation expense recognized for restricted stock grants was
$49,000, $41,000 and $41,000 for the years ended December 31, 1993, 1994 and
1995, respectively.
(10) INCOME TAXES
Deferred tax assets (liabilities) at December 31, 1994 and 1995 are
comprised of the following:
<TABLE>
<CAPTION>
1994 1995
------- --------
(IN THOUSANDS)
<S> <C> <C>
Net deferred tax asset
Property and equipment...................................... $(5,079) $ 2,548
Net operating loss carryforwards............................ 9,250 10,544
Valuation allowance......................................... (4,171) (13,092)
------- --------
$ -- $ --
======= ========
</TABLE>
No income tax provision was recognized in 1993, 1994 or 1995 due to the
availability of net operating loss carryforwards to offset any current or
deferred income tax liabilities.
Prior to November 17, 1993, Stanford was a Subchapter S corporation and, as
a result, the income or loss of Stanford for the period from Stanford's
inception to November 17, 1993, for income tax purposes, is includable in the
tax returns of the Stanford stockholders. Accordingly, no recognition has been
given to income taxes relating to the operations of Stanford from August 31,
1992 to November 17, 1993 in the accompanying financial statements. Prior to the
merger, Stanford paid $1,152,000 in distributions to its shareholders in 1993.
Such distributions were based on the estimated income tax liability that the
Stanford shareholders had as a result of their ownership in Stanford.
The Company has net operating loss carryforwards of approximately $31.0
million as of December 31, 1995, for income tax reporting purposes which expire
in varying amounts from 2001 to 2010. The utilization of a portion of the net
operating loss carryforwards is limited in a given year due to ownership changes
which have occurred.
(11) RELATED PARTY TRANSACTIONS
The Company serves as general partner of Comstock DR-II Oil & Gas
Acquisition Limited Partnership ("Comstock DR-II"). For 1993, 1994 and 1995 the
Company received $87,000 in management fees each year from Comstock DR-II and
earned acquisition fees from Comstock DR-II of approximately $180,000 and
$56,000 in 1993 and 1994, respectively. Included in accounts receivable in the
accompanying financial statements is approximately $208,000 and $380,000
receivable from Comstock DR-II at December 31, 1994 and 1995, respectively.
From October through December 1994, the Company purchased an additional 17%
working interest in the Bivins Ranch lease covering certain oil and gas
properties in the Texas Panhandle field from certain of the
F-16
<PAGE> 68
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Company's shareholders, including trusts for the benefit of two of the Company's
directors' family members, certain relatives of one of the Company's directors
and other unaffiliated investors. The Company paid for the purchase of such
interests by assuming outstanding joint interest payables on the properties
aggregating $186,000, paying $365,000 in cash and by granting the sellers
options to purchase an aggregate of 503,557 shares of the Company's common stock
at a price of $5.00 per share. The options expire five years from the date of
grant.
Beginning on August 1, 1995, the Company became the managing general
partner and acquired a 20.31% limited partner interest in Crosstex Pipeline
Partners, Ltd. ("Crosstex"). The Company received $39,000 in fees for management
and construction services provided to Crosstex in 1995. In addition, Crosstex
reimbursed the Company $104,000 for direct expenses incurred in connection with
managing Crosstex. Crosstex transports natural gas and sells natural gas to the
Company. In 1995 the Company had $546,000 in natural gas purchases from Crosstex
and paid $158,000 to Crosstex for transportation.
Included in accounts payable and accrued natural gas purchases in the
accompanying financial statements at December 31, 1995 is approximately $381,000
payable to Crosstex. Included in accounts receivable in the accompanying
financial statements at December 31, 1995 is approximately $57,000 receivable
from Crosstex.
(12) PRICE RISK MANAGEMENT
The Company periodically uses derivative financial instruments to manage
natural gas price risk. The Company's realized gains and losses attributable to
its price risk management activities are as follows:
<TABLE>
<CAPTION>
1994 1995
---- ----
(IN THOUSANDS)
<S> <C> <C>
OIL AND GAS PRODUCING ACTIVITIES
Realized Gains........................................... $726 $913
Realized Losses.......................................... $ 9 $ 28
GAS GATHERING, PROCESSING AND MARKETING ACTIVITIES
Realized Gains........................................... $ 15 $895
Realized Losses.......................................... $ 30 $373
</TABLE>
Set forth below is the contract amount and terms of all instruments held
for price risk management purposes at December 31, 1994 and 1995:
OIL AND GAS PRODUCING ACTIVITIES
<TABLE>
<CAPTION>
YEAR INSTRUMENT QUANTITY PRICE REMAINING TERM
- ---- ----------------------- --------------- -------------- -----------------------
<C> <S> <C> <C> <C>
1994 Natural Gas Price Swaps 9,087,434 MMBtu $2.00 Jan. 1995 to Nov. 1999
1995 -- None -- --
</TABLE>
GAS MARKETING ACTIVITIES
<TABLE>
<CAPTION>
YEAR INSTRUMENT QUANTITY PRICE REMAINING TERM
- ---- ----------------------- --------------- -------------- -----------------------
<C> <S> <C> <C> <C>
1994 Natural Gas Price Swaps 1,670,000 MMBtu $1.57 to $2.06 Jan. 1995 to Oct. 1995
1995 Natural Gas Price Swaps 533,000 MMBtu $1.63 to $1.80 Jan. 1996 to Aug. 1996
</TABLE>
During 1995, the Company settled open swap positions relating to term
January 1996 to November 1999 and received a $430,000 cash payment. This amount
is reflected as deferred revenue in the accompanying balance sheet at December
31, 1995.
F-17
<PAGE> 69
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
During the first quarter of 1996, the Company entered into natural gas
price swap agreements to hedge 2,905,000 MMBtu of its natural gas production
during the term March 1996 to December 1996 at an average price of $1.90 per
MMBtu.
(13) INDUSTRY SEGMENT INFORMATION
Beginning in June 1994, the Company operates in two business segments, all
in the United States, as follows:
Oil and Gas. The Company is engaged in the acquisition, development and
production of oil and natural gas.
Gas Gathering, Processing and Marketing. The Company markets natural gas
and gathers, processes and transports natural gas through its facilities.
Financial information by industry segment is as follows:
<TABLE>
<CAPTION>
1994 1995
------- --------
(IN THOUSANDS)
<S> <C> <C>
Revenues:
Oil and gas................................................... $16,855 $ 22,091
Gas marketing, processing and gathering(1).................... 15,029 50,678
------- --------
$31,884 $ 72,769
======= ========
Operating Profit (Loss):
Oil and gas(2)................................................ $ 3,607 $(22,763)
Gas marketing, processing and gathering(2).................... 490 1,440
------- --------
$ 4,097 $(21,323)
======= ========
Identifiable Assets:
Oil and gas................................................... $76,842 $ 99,661
Gas marketing, processing and gathering....................... 1,005 2,322
------- --------
$77,847 $101,983
======= ========
Capital Expenditures:
Oil and gas................................................... $15,066 $ 59,759
Gas marketing, processing and gathering....................... 1,099 2,009
------- --------
$16,165 $ 61,768
======= ========
Depreciation, Depletion and Amortization:
Oil and gas................................................... $ 7,149 $ 8,277
Gas marketing, processing and gathering....................... 8 120
------- --------
$ 7,157 $ 8,397
======= ========
</TABLE>
- ---------------
(1) Intersegment revenues which are not included in gas marketing and gathering
revenues were $2,033,000 in 1994 and $7,788,000 in 1995.
(2) Total interest expense and total general and administrative expense are not
allocated to the segments.
Sales to one purchaser of the Company's natural gas production accounted
for 43% and 21% of total oil and gas sales in 1993 and 1994, respectively. Sales
to this natural gas purchaser also accounted for 28% and 18% of gas marketing
sales in 1994 and 1995, respectively. No single purchaser accounted for more
than 10% of oil and gas sales in 1995.
F-18
<PAGE> 70
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
(14) OIL AND GAS RESERVES INFORMATION (UNAUDITED)
The estimates of proved oil and gas reserves utilized in the preparation of
the financial statements were estimated by independent petroleum engineers in
accordance with guidelines established by the Securities and Exchange Commission
and the Financial Accounting Standards Board, which require that reserve reports
be prepared under existing economic and operating conditions with no provision
for price and cost escalation except by contractual agreement. All of the
Company's reserves are located onshore in or offshore to the continental United
States.
Future prices received for production and future production costs may vary,
perhaps significantly, from the prices and costs assumed for purposes of these
estimates. There can be no assurance that the proved reserves will be developed
within the periods indicated or that prices and costs will remain constant.
There can be no assurance that actual production will equal the estimated
amounts used in the preparation of reserve projections.
There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future rates of production and timing of
development expenditures. Oil and gas reserve engineering must be recognized as
a subjective process of estimating underground accumulations of oil and gas that
cannot be measured in an exact way, and estimates of other engineers might
differ materially from those shown below. The accuracy of any reserve estimate
is a function of the quality of available data and engineering and geological
interpretation and judgment. Results of drilling, testing and production after
the date of the estimate may justify revisions. Accordingly, reserve estimates
are often materially different from the quantities of oil and gas that are
ultimately recovered. Reserve estimates are integral in management's analysis of
impairments of oil and gas properties and the calculation of depreciation,
depletion and amortization on those properties.
The following unaudited table sets forth proved oil and gas reserves at
December 31, 1993, 1994 and 1995:
<TABLE>
<CAPTION>
1993 1994 1995
------------------ ----------------- ------------------
OIL GAS OIL GAS OIL GAS
(MBBLS) (MMCF) (MBBLS) (MMCF) (MBBLS) (MMCF)
------- ------- ------- ------ ------- -------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Proved Reserves:
Beginning of year.................. 2,259 76,061 6,111 74,363 5,119 92,840
Revisions of previous
estimates..................... 1,776 (16,703) (1,135) (3,301) (2,843) (18,810)
Extensions and discoveries...... -- -- 19 4,453 -- --
Purchases of minerals in
place(1)...................... 2,512 25,117 388 23,466 1,859 108,432
Sales of minerals in place...... (158) (2,838) (1) (84) -- --
Production(2)................... (278) (7,274) (263) (6,057) (356) (9,297)
----- ------- ------ ------ ------ -------
End of year........................ 6,111 74,363 5,119 92,840 3,779 173,165
===== ======= ====== ====== ====== =======
Proved Developed Reserves:
Beginning of year.................. 816 32,195 1,655 42,909 1,504 62,827
----- ------- ------ ------ ------ -------
End of year........................ 1,655 42,909 1,504 62,827 2,562 130,375
===== ======= ====== ====== ====== =======
</TABLE>
- ---------------
(1) 1994 purchases of minerals in place include the repurchase of a volumetric
production payment of 10,722,000 Mcf.
(2) Excludes 1,240,000 and 456,000 Mcf of gas production delivered to a major
natural gas company under a volumetric production payment in 1993 and 1994,
respectively.
F-19
<PAGE> 71
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
Standardized Measure of Discounted Future Net Cash Flows Relating to Proved
Reserves at December 31, 1994 and 1995:
<TABLE>
<CAPTION>
1994 1995
-------- ---------
(IN THOUSANDS)
<S> <C> <C>
Cash Flows Relating to Proved Reserves:
Future Cash Flows................................................... $243,811 $ 426,131
Future Costs:
Production....................................................... (73,899) (121,727)
Development...................................................... (25,366) (39,462)
-------- ---------
Future Net Cash Flows Before Income Taxes........................... 144,546 264,942
Future Income Taxes................................................. (17,028) (45,175)
-------- ---------
Future Net Cash Flows............................................... 127,518 219,767
10% Discount Factor................................................. (49,037) (73,261)
-------- ---------
Standardized Measure of Discounted Future Net Cash Flows.............. $ 78,481 $ 146,506
======== =========
</TABLE>
Changes in Standardized Measure of Discounted Future Net Cash Flows
Relating to Proved Reserves for the years ended December 31, 1993, 1994 and
1995:
<TABLE>
<CAPTION>
1993 1994 1995
-------- -------- --------
(IN THOUSANDS)
<S> <C> <C> <C>
Standardized Measure, Beginning of Year.................... $ 45,335 $ 60,757 $ 78,481
Net Change in Sales Price, Net of Production Costs....... (4,047) (3,392) 9,450
Development Costs Incurred During the Year Which Were
Previously Estimated.................................. -- 347 822
Revisions of Quantity Estimates.......................... (4,062) (6,457) (30,298)
Accretion of Discount.................................... 4,545 6,095 7,874
Changes in Future Development Costs...................... 9,545 2,695 13,248
Changes in Timing and Other.............................. (7,425) (2,883) (2,590)
Extensions and Discoveries............................... -- 3,582 --
Purchases of Reserves In Place........................... 32,551 28,083 85,706
Sales of Reserves In Place............................... (2,073) (84) --
Sales, Net of Production Costs........................... (13,529) (10,194) (14,664)
Net Changes in Income Taxes.............................. (83) (68) (1,523)
-------- -------- --------
Standardized Measure, End of Year.......................... $ 60,757 $ 78,481 $146,506
======== ======== ========
</TABLE>
F-20
<PAGE> 72
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)
ASSETS
<TABLE>
<CAPTION>
DECEMBER 31 SEPTEMBER 30,
1995 1996
----------- -------------
(UNAUDITED)
<S> <C> <C>
Cash and Cash Equivalents.......................................... $ 1,917 $ 11,119
Accounts Receivable:
Oil and gas sales................................................ 5,385 12,532
Gas marketing sales.............................................. 8,451 7,863
Joint interest operations........................................ 1,230 1,685
Other Current Assets............................................... 264 323
-------- --------
Total current assets..................................... 17,247 33,522
-------- --------
Property and Equipment:
Oil and gas properties, successful efforts method................ 154,844 248,719
Other............................................................ 2,717 2,777
Accumulated depreciation, depletion and amortization............. (55,445) (63,263)
-------- --------
Net property and equipment............................... 102,116 188,233
-------- --------
Other Assets....................................................... 736 628
-------- --------
$ 120,099 $ 222,383
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Portion of Long-term Debt.................................. $ 18,677 $ 171
Accounts Payable and Accrued Expenses.............................. 16,511 22,049
-------- --------
Total current liabilities................................ 35,188 22,220
-------- --------
Long-term Debt, less current portion............................... 53,134 150,009
Deferred Revenue................................................... 430 108
Other Noncurrent Liabilities....................................... 1,219 1,096
Stockholders' Equity:
Preferred stock -- $10.00 par, 5,000,000 shares authorized;
1,500,000 and 3,100,000 shares outstanding at September 30,
1996 and December 31, 1995, respectively...................... 31,000 15,000
Common stock -- $.50 par, 30,000,000 shares authorized;
17,340,742 and 12,926,672 shares outstanding at September 30,
1996 and December 31, 1995, respectively...................... 6,463 8,670
Additional paid-in capital....................................... 38,183 55,154
Retained deficit................................................. (45,444) (29,832)
Less: Deferred compensation -- restricted stock grants........... (74) (42)
-------- --------
Total stockholders' equity............................... 30,128 48,950
-------- --------
$ 120,099 $ 222,383
======== ========
</TABLE>
The accompanying notes are an integral part of these statements.
F-21
<PAGE> 73
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1995 AND 1996
(UNAUDITED)
<TABLE>
<CAPTION>
1995 1996
------- -------
(IN THOUSANDS
EXCEPT PER SHARE
AMOUNTS)
<S> <C> <C>
Revenues:
Oil and gas sales...................................................... $14,254 $45,517
Gas marketing sales.................................................... 34,786 67,574
Gas gathering and processing........................................... 454 540
Gain on sales of property.............................................. 2,608 1,506
Other income........................................................... 206 455
------- -------
Total revenues.................................................... 52,308 115,592
------- -------
Expenses:
Oil and gas operating.................................................. 4,803 9,673
Natural gas purchases.................................................. 33,974 66,104
Gas gathering and processing........................................... 135 197
Exploration............................................................ -- 285
Depreciation, depletion and amortization............................... 6,114 12,809
General and administrative, net........................................ 1,448 1,546
Interest............................................................... 3,574 7,619
------- -------
Total expenses.................................................... 50,048 98,233
------- -------
Income before income taxes............................................... 2,260 17,359
Provision for income taxes............................................... -- --
------- -------
Net income............................................................... 2,260 17,359
Preferred stock dividends................................................ (1,267) (1,747)
------- -------
Net income attributable to common stock.................................. $ 993 $15,612
======= =======
Net income attributable to common stock per share --
Primary................................................................ $ 0.08 $ 1.04
======= =======
Fully diluted.......................................................... $ 0.82
=======
Weighted average number of common shares and common stock equivalent
shares outstanding --
Primary................................................................ 12,843 15,014
======= =======
Fully diluted.......................................................... 21,246
=======
</TABLE>
The accompanying notes are an integral part of these statements.
F-22
<PAGE> 74
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF STOCKHOLDERS' EQUITY
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1996
(UNAUDITED)
<TABLE>
<CAPTION>
DEFERRED
ADDITIONAL RETAINED COMPENSATION-
PREFERRED COMMON PAID-IN EARNINGS RESTRICTED
STOCK STOCK CAPITAL (DEFICIT) STOCK GRANTS TOTAL
-------- ------ ---------- -------- ------------- -------
(IN THOUSANDS)
<S> <C> <C> <C> <C> <C> <C>
Balance at December 31, 1995....... $ 31,000 $6,463 $ 38,183 $(45,444) $ (74) $30,128
Conversion of preferred stock.... (16,000) 1,750 14,250 -- -- --
Issuance of common stock......... -- 457 2,721 -- -- 3,178
Restricted stock grants.......... -- -- -- -- 32 32
Net income attributable
to common stock............... -- -- -- 15,612 -- 15,612
-------- ------ ------- -------- ---- ------
Balance at September 30, 1996...... $ 15,000 $8,670 $ 55,154 $(29,832) $ (42) $48,950
======== ====== ======= ======== ==== ======
</TABLE>
The accompanying notes are an integral part of these statements.
F-23
<PAGE> 75
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
FOR THE NINE MONTHS ENDED SEPTEMBER 30
(UNAUDITED)
<TABLE>
<CAPTION>
1995 1996
-------- ---------
(IN THOUSANDS)
<S> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income.......................................................... $ 2,260 $ 17,359
Adjustments to reconcile net income to net cash
provided by operating activities:
Compensation paid in common stock................................ 144 185
Depreciation, depletion and amortization......................... 6,114 12,809
Deferred revenue................................................. 430 (322)
Exploration...................................................... -- 285
Gain on sales of property........................................ (2,608) (1,506)
-------- ---------
Working capital provided by operations...................... 6,340 28,810
Increase in accounts receivable..................................... (1,783) (7,015)
(Increase) decrease in other current assets......................... 29 (58)
Increase (decrease) in accounts payable and accrued expenses........ (1,590) 5,538
-------- ---------
Net cash provided by operating activities........................... 2,996 27,275
-------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures and acquisitions............................... (59,708) (106,668)
Proceeds from sales of properties................................... 2,995 8,948
-------- ---------
Net cash used for investing activities.............................. (56,713) (97,720)
-------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from preferred stock issuance.............................. 15,000 --
Dividends paid on preferred stock................................... -- (428)
Proceeds from common stock issuance................................. 25 1,720
Stock issuance costs................................................ (90) (15)
Borrowings.......................................................... 58,403 172,150
Principal payments on debt.......................................... (22,077) (93,780)
-------- ---------
Net cash provided by financing activities........................ 51,261 79,647
-------- ---------
Net increase (decrease) in cash and cash equivalents............. (2,456) 9,202
Cash and cash equivalents, beginning of year..................... 3,425 1,917
-------- ---------
Cash and cash equivalents, end of period......................... $ 969 $ 11,119
======== =========
</TABLE>
The accompanying notes are an integral part of these statements.
F-24
<PAGE> 76
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 1996 AND 1995
(UNAUDITED)
(1) SIGNIFICANT ACCOUNTING POLICIES
BASIS OF PRESENTATION
In management's opinion, the accompanying consolidated financial statements
contain all adjustments (consisting solely of normal recurring adjustments)
necessary to present fairly the financial position of Comstock Resources, Inc.
and subsidiaries (the "Company") as of September 30, 1996 and the related
results of operations for the nine months ended September 30, 1995 and 1996 and
cash flows for the nine months ended September 30, 1995 and 1996.
The accompanying unaudited financial statements have been prepared pursuant
to the rules and regulations of the Securities and Exchange Commission. Certain
information and disclosures normally included in annual financial statements
prepared in accordance with generally accepted accounting principles have been
omitted pursuant to those rules and regulations, although the Company believes
that the disclosures made are adequate to make the information presented not
misleading. These financial statements should be read in conjunction with the
Company's financial statements and notes thereto included in the Company's
Annual Report on Form 10-K for the year ended December 31, 1995.
The results of operations for the nine months ended September 30, 1995 and
1996, are not necessarily an indication of the results expected for the full
year.
SUPPLEMENTARY INFORMATION WITH RESPECT TO THE STATEMENTS OF CASH FLOWS
The Company paid cash for interest of $3,574,000 and $7,349,000 during the
nine months ended September 30, 1995 and 1996, respectively. No cash for income
taxes was paid in the nine months ended September 30, 1995 and 1996.
The following is a summary of the significant noncash investing and
financing activities:
<TABLE>
<CAPTION>
FOR THE NINE MONTHS
ENDED SEPTEMBER 30,
---------------------
1995 1996
------ ------
(IN THOUSANDS)
<S> <C> <C>
Common stock issued for director compensation.................. $ 113 $ 154
Common stock issued for preferred stock dividends.............. $1,267 $1,319
</TABLE>
EARNINGS PER SHARE
Net income attributable to common stock represents net income less
preferred stock dividend requirements of $1,267,000 and $1,747,000 for the nine
months ended September 30, 1995 and 1996, respectively. Net income attributable
to common stock per share is computed by dividing net income attributable to
common stock by the weighted average number of common shares and common stock
equivalents outstanding during each period. Common stock equivalents include,
when applicable, dilutive stock options and warrants using the treasury stock
method. Fully diluted net income attributable to common stock per share includes
the dilutive effect of the Company's convertible preferred stock using the "if
converted" method and dilutive stock options and warrants using the treasury
stock method.
(2) OIL & GAS PROPERTY ACQUISITION
On May 1 and May 2, 1996, the Company completed a $104 million purchase of
working interests in the Double A Wells field in Polk County, Texas. The Company
acquired 100% of the capital stock of Black Stone
F-25
<PAGE> 77
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS -- (CONTINUED)
SEPTEMBER 30, 1996 AND 1995
(UNAUDITED)
Oil Company, the operator of the field, together with additional interests held
by other working interest owners in nineteen producing oil and gas properties as
well as interests in adjacent undeveloped oil and gas leases. The interests were
acquired effective January 1, 1996. Accordingly, revenues from the properties
net of operating and development costs attributable to the period January 1,
1996 to April 30, 1996 were recorded as a reduction of the purchase price paid
for the properties. The net proved oil and natural gas reserves attributable to
the interests acquired are estimated at 5.3 million barrels of oil and 98.5
billion cubic feet of natural gas as of January 1, 1996.
(3) LONG-TERM DEBT
In connection with the $104 million oil and gas property acquisition closed
in May 1996, the Company entered into a $176 million credit facility with two
banks, consisting of a $166 million revolving credit commitment and a $10
million short-term bridge loan. The new revolving credit facility converts to a
two year term loan on May 1, 1999. The Company financed the $104 million
acquisition and refinanced $68.7 million outstanding under its existing bank
credit facility with borrowings under the new bank credit facility. On May 15,
1996, the Company repaid the $10 million bridge loan primarily from proceeds
from certain asset sales. On August 13, 1996, the Company refinanced the $166
million credit facility with a syndication of eleven banks in which The First
National Bank of Chicago serves as agent. The new revolving credit facility will
convert to a term loan on August 13, 1999. The term loan is to be repaid in
consecutive quarterly installments of 5% of the original outstanding principal
balance with the final balance due in full on August 13, 2001.
As of September 30, 1996, the Company had $150 million outstanding under
the new bank revolving credit facility. Borrowings under the new bank credit
facility cannot exceed a borrowing base determined semiannually by the banks.
The borrowing base at September 30, 1996 was $166 million. Amounts outstanding
under the new bank credit facility bear interest at a floating rate based on The
First National Bank of Chicago's base rate (as defined) plus 1/2% or, at the
Company's option, at a fixed rate for up to six months based on the London
Interbank Offered Rate ("LIBOR") plus 1.25% to 2% depending upon the utilization
of the available borrowing base. As of September 30, 1996, the Company had
placed the outstanding advances under the revolving credit facility under fixed
rate loans based on LIBOR at an average rate of approximately 7.56% per annum.
(4) SALE OF OIL AND GAS PROPERTIES
In May 1996, the Company sold certain oil and gas properties for
approximately $8.9 million. The properties sold include interests in 145
producing wells located in Oklahoma, Arkansas, Nebraska and Kansas as well as
the Company's interests in the Chapman Ranch field in South Texas. The
properties sold were non-strategic assets to the Company and were located out of
the Company's primary operating areas. A gain from the sales of $1.5 million is
included in the accompanying statement of operations.
(5) CONVERSION OF PREFERRED STOCK TO COMMON STOCK
On July 11, 1996, the Company redeemed the 1,000,000 shares of the 1994
Series B Convertible Preferred Stock, $10 par value per share, by issuing
2,000,000 shares of common stock of the Company. The conversion of the 1994
Series B Convertible Preferred Stock into common stock will reduce the dividends
paid on the preferred stock in the future by $625,000 per annum.
On September 16, 1996 the holders of the Series 1994 Convertible Preferred
Stock, converted all of the shares of the Series 1994 Convertible Preferred
Stock, $10 par value per share, into 1,500,000 shares of common stock of the
Company. The conversion of the Series 1994 Convertible Preferred Stock into
common stock will reduce the dividends paid on the preferred stock in the future
by $540,000 per annum.
F-26
<PAGE> 78
APPENDIX A
LEE KEELING AND ASSOCIATES, INC.
PETROLEUM CONSULTANTS
3500 FIRST PLACE TOWER
15 EAST 5TH STREET
TULSA, OKLAHOMA 74103-4350 USA
(918) 587-5521
FACSIMILE 587-2881
October 23, 1996
Comstock Resources, Inc.
Occidental Tower, Suite 1000
5005 LBJ Freeway
Dallas, Texas 75244
Attention: Mr. M. Jay Allison,
President and C.E.O.
Re: Comstock Resources, Inc.
Combination of Appraisals
Gentlemen:
Lee Keeling and Associates, Inc. has prepared appraisals of interests owned
by Comstock Resources, Inc. A report, dated February 28, 1996, includes
interests owned as of January 1, 1996. A second report, dated May 1, 1996,
includes interests acquired in the Black Stone Oil Company acquisition. A third
report, dated May 9, 1996, includes properties divested of by Comstock in early
1996. The effective date of all reports is January 1, 1996. The results of the
third report were deducted from the sum of the first and the second reports.
Exhibit No. 1 shows the results of each individual report and the three reports
are summarized as follows:
<TABLE>
<CAPTION>
ESTIMATED REMAINING FUTURE NET REVENUE
NET RESERVES ------------------------------
------------------------- PRESENT VALUE
RESERVE OIL GAS DISCOUNTED @
CLASSIFICATION (BBLS) (MCF) TOTAL 10%
------------------------------ --------- ----------- ------------ -------------
<S> <C> <C> <C> <C>
Proved Developed
Producing................... 4,767,318 125,750,596 $258,248,002 $ 168,944,248
Non-Producing............... 878,525 19,045,845 46,274,021 27,663,908
Behind-Pipe................. 551,958 45,102,874 70,484,163 25,620,748
Proved Undeveloped
Primary..................... 2,272,709 67,222,672 117,769,935 64,177,615
--------- ----------- ------------ -------------
Total All
Reserves.......... 8,470,510 257,121,987 $492,776,121 $ 286,406,519
========= =========== ============ =============
</TABLE>
Future net revenue is the amount, exclusive of state and federal income
taxes, which will accrue to the appraised interests from continued operation of
the properties to depletion. It should not be construed as a fair market or
trading value. With the exception of the properties included in the Bois D'Arc
acquisition, no provision has been made for the cost of plugging and abandoning
the properties nor for the value of salvable equipment. The Bois D'Arc
acquisition is comprised of off-shore properties for which abandonment charges
must be considered.
No attempt has been made to quantify or otherwise account for any
accumulative gas production imbalances that may exist. Neither has an attempt
been made to determine whether the wells and facilities are in compliance with
various governmental regulations, nor have costs been included in the event they
are not.
A-1
<PAGE> 79
CLASSIFICATION OF RESERVES
Reserves attributed to the appraised leases have been classified as "proved
developed producing," "proved developed non-producing," "proved developed
behind-pipe" and "proved undeveloped primary."
Proved Developed Producing Reserves are those reserves expected to be
recovered from currently producing zones under continuation of present operating
methods. This category may also include recently completed shut-in gas wells
scheduled for connection to a pipeline in the near future.
Proved Developed Non-Producing Reserves are those reserves expected to be
recovered from zones capable of producing but which are shut-in because no
market outlet exists at the present time or whose date of connection to a
pipeline is uncertain.
Proved Developed Behind-Pipe Reserves are those reserves currently behind
the pipe in existing wells which are considered proved by virtue of successful
testing or production in offsetting wells.
Proved Undeveloped Primary Reserves are those reserves attributable to
wells to be drilled at locations which can be anticipated with a high degree of
certainty.
ESTIMATION OF RESERVES
Comstock Year-End
The majority of the appraised wells have been producing for a considerable
length of time. Reserves attributable to wells with a well-defined production
and/or pressure decline trend were based upon extrapolation of that trend to an
economic limit and/or abandonment pressure.
Reserves anticipated from new wells were based upon volumetric calculations
or analogy with similar properties which are producing from the same horizons in
the respective areas. Structural position, net pay thickness, well productivity,
gas/oil ratios, water production, pressures, and other pertinent factors were
considered in the estimations of these reserves.
Reserves assigned to behind-pipe zones have been estimated based on
volumetric calculations and/or analogy with other wells in the area producing
from the same horizon.
Black Stone Oil Company Acquisition
As of January 1, 1996, eighteen wells had been drilled and completed in the
Double A Wells Field. Sixteen were producing with the remaining two scheduled to
begin producing in the next few weeks. The first wells began producing in 1988
and the most recent, early in January, 1996. Performance of the wells has
established the presence of four compartments or pressure regimes. These
compartments are identified as groups and the number of wells in each group and
cumulative recovery are as follows:
<TABLE>
<CAPTION>
CUMULATIVE RECOVERY
------------------------
GROUP PRODUCING OIL GAS
(COMPARTMENT) WELLS (BBLS) (MCF)
-------------------------------------------------- --------- --------- ----------
<S> <C> <C> <C>
Trostman.......................................... 5 325,900 19,688,700
A/C 2+4........................................... 2 978,000 10,914,505
Jackson........................................... 1 145,400 2,311,600
New Carter Group.................................. 8* 1,445,900 24,100,300
--
--------- ----------
Total................................... 16 2,895,200 57,015,105
== ========= ==========
</TABLE>
- ---------------
* Includes one well on line January, 1996.
The Trostman wells are all producing below the dew point and all have
well-established production decline trends. Reserves attributable to these wells
have been estimated by extrapolation of established production decline trends
with consideration given to bottom-hole pressure versus cumulative recovery
relationships.
A-2
<PAGE> 80
A/C 2+4 wells are still producing above the dew point and reserves have
been estimated by extrapolation of bottom-hole pressure versus cumulative
recovery relationships to an abandonment pressure. Liquid reserves have been
based on fluid analysis (PVT) data.
The single Jackson well reserves have been estimated by extrapolation of
the production decline curve to an economic limit.
New Carter Group reserves were estimated by extrapolation of the composite
reservoir bottom-hole pressure versus cumulative-recovery relationship to an
abandonment pressure. Gas-in-place volumes so determined were confirmed by
volumetric calculations. Reservoir pressure is considerably above the dew point
and liquid reserve assignments have been based on fluid analysis data. Reserves
were allocated to the individual producing wells on the basis of productive
capacities and net pay thicknesses.
Estimation of the New Carter Group reserves were revised upward from those
in the first appraisal to recognize additional pay volumes revealed by the
drilling of Champion "C" No. 2. This well was drilled subsequent to the
effective date of the appraisal but the reserves attributable to it are still
classified as "proved undeveloped."
Initial producing rates of certain wells were also adjusted, upward or
downward, to more accurately reflect actual field conditions.
Allocations of reserves to the two shut-in wells were made on the basis of
indicated productivity and net pay thickness. It is anticipated that three
additional wells will be drilled in the next one-to-two years. (This includes
Champion "C" No. 2.) Reserves allocated to these wells have been based on
anticipated productive capacities, net pay thicknesses and by analogy to nearby
wells.
Gothic/Shell Divestiture
Properties included in the Gothic Energy or Mid-Continent Divestiture
involve approximately 125 properties in the states of Arkansas, Kansas, Nebraska
and Oklahoma. The sale to Shell involved the "Chapman Wells" and included one
producing well plus one well to which behind-pipe reserves had been assigned.
Proved undeveloped reserves had been assigned to two locations on the properties
sold to Shell.
The proved reserves included in this report conform to the applicable
definition promulgated by the Securities and Exchange Commission.
FUTURE NET REVENUE
Oil Income
Income from the sale of oil for the various areas was estimated using an
initial price of $18.00 per barrel as requested by Comstock Resources, Inc. This
price was held constant throughout the life of each property. Provisions were
made for state severance and ad valorem taxes where applicable.
Gas Income
Income from the sale of gas was based upon current gas prices being
received for gas sold from each well as provided by the staff of Comstock
Resources, Inc. These prices were held constant throughout the life of each
property. Adjustments were made for state severance and ad valorem taxes where
applicable.
Operating Expenses
Operating expenses were based upon actual operating costs charged by the
respective operators as supplied by the staff of Comstock Resources, Inc. or
were based upon the actual experience of the operators in the respective areas.
For leases operated by Comstock Resources, Inc., monthly lease operating
expenses do not include overhead charges. All expenses have been held constant
throughout the life of each lease.
A-3
<PAGE> 81
Future Expenses and Abandonment Costs
Future expenses required for drilling and recompletion and abandonment
costs for the off-shore properties have been estimated by Comstock Resources,
Inc. These costs have been held constant from current estimates.
GENERAL
Information upon which this appraisal has been based was furnished by the
staff of Comstock Resources, Inc. or was obtained by us from outside sources we
consider to be reliable. This information is assumed to be correct. No attempt
has been made to verify title or ownership of the appraised properties.
This report has been prepared utilizing methods and procedures regularly
used by petroleum engineers to estimate oil and gas reserves for properties of
this type and character. The recovery of oil and gas reserves and projection of
producing rates are dependent upon many variable factors including prudent
operation, compression of gas when needed, market demand, installation of
lifting equipment, and remedial work when required. The reserves included in
this report have been based upon the assumption that the wells will be operated
in a prudent manner under the same conditions existing on the effective date.
Actual production results and future well data may yield additional facts, not
presently available to us, which will require an adjustment to our estimates.
The reserves included in this report are estimates only and should not be
construed as being exact quantities. They may or may not be actually recovered,
and, if recovered, the revenues therefrom and the actual costs related thereto
could be more or less than the estimated amounts. As in all aspects of oil and
gas evaluation, there are uncertainties inherent in the interpretation of
engineering data and, therefore, our conclusions necessarily represent only
informed professional judgments.
The projection of cash flow has been made assuming constant prices. There
is no assurance that prices will not vary. For this reason and those listed in
the previous paragraph, the future net cash from the sale of production from the
appraised properties may vary from the estimates contained in this report.
The information developed during the course of this investigation, basic
data, maps and worksheets showing recovery determinations are available for
inspection in our office.
We appreciate this opportunity to be of service to you.
Very truly yours,
/s/ LEE KEELING AND ASSOCIATES, INC.
Lee Keeling and Associates, Inc.
A-4
<PAGE> 82
EXHIBIT 1
COMSTOCK RESOURCES, INC.
EFFECTIVE DATE: JANUARY 1, 1996
<TABLE>
<CAPTION>
FUTURE NET REVENUE
ESTIMATED REMAINING ----------------------------
NET RESERVES PRESENT
------------------------ VALUE
RESERVE OIL GAS DISCOUNTED @
CLASSIFICATION (BARRELS) (MCF) TOTAL 10%
- ----------------------------------------- --------- ----------- ------------ ------------
<S> <C> <C> <C> <C>
COMSTOCK YEAR-END
--------------------------------------------------------
Proved Developed
Producing.............................. 1,937,217 79,473,369 $129,075,012 $ 88,404,387
Non-Producing.......................... 40,987 5,702,758 8,436,278 5,418,416
Behind-Pipe............................ 584,277 45,199,146 70,922,471 25,859,631
Proved Undeveloped
Primary................................ 1,216,548 42,790,071 56,508,325 28,609,998
--------- ---------- ------------ ------------
Total Comstock Year-End
All Reserves................. 3,779,029 173,165,344 $264,942,086 $148,292,432
========= ========== ============ ============
BLACK STONE OIL COMPANY ACQUISITION
--------------------------------------------------------
Proved Developed
Producing.............................. 2,956,891 55,488,025 $140,634,083 $ 86,939,813
Non-Producing.......................... 837,538 15,342,921 39,300,581 22,897,605
Proved Undeveloped
Primary................................ 1,507,203 27,717,843 68,677,321 38,751,015
--------- ---------- ------------ ------------
Total Black Stone Oil Company
Acquisition All Reserves..... 5,301,632 98,548,789 $248,611,985 $148,588,433
========= ========== ============ ============
GOTHIC/SHELL DIVESTITURE
--------------------------------------------------------
Proved Developed
Producing.............................. 126,790 9,210,798 $ 11,461,093 $ 6,399,952
Non-Producing.......................... 0 1,999,834 1,462,838 652,113
Behind-Pipe............................ 32,319 96,332 438,308 238,883
Proved Undeveloped
Primary................................ 451,042 3,285,242 7,415,711 3,183,398
--------- ---------- ------------ ------------
Total Gothic/Shell Divestiture
All Reserves................. 610,151 14,592,206 $ 20,777,950 $ 10,474,346
========= ========== ============ ============
TOTAL RESERVES -- COMBINATION APPRAISALS
--------------------------------------------------------
Proved Developed
Producing.............................. 4,767,318 125,750,596 $258,248,002 $168,944,248
Non-Producing.......................... 878,525 19,045,845 46,274,021 27,663,908
Behind-Pipe............................ 551,958 45,102,874 70,484,163 25,620,748
Proved Undeveloped
Primary................................ 2,272,709 67,222,672 117,769,935 64,177,615
--------- ---------- ------------ ------------
Total-Combination Appraisal
All Reserves................. 8,470,510 257,121,987 $492,776,121 $286,406,519
========= =========== ============ ============
</TABLE>
<PAGE> 83
================================================================================
NO DEALER, SALESPERSON OR OTHER PERSON IS AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATION OTHER THAN THOSE CONTAINED IN THIS
PROSPECTUS, AND, IF GIVEN OR MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT
BE RELIED UPON AS HAVING BEEN AUTHORIZED. THIS PROSPECTUS DOES NOT CONSTITUTE AN
OFFER TO SELL OR A SOLICITATION OF AN OFFER TO BUY ANY SECURITY OTHER THAN THE
SECURITIES OFFERED HEREBY, NOR DOES IT CONSTITUTE AN OFFER TO SELL OR A
SOLICITATION OF AN OFFER TO BUY ANY OF THE SECURITIES OFFERED HEREBY TO ANY
PERSON IN ANY CIRCUMSTANCES IN WHICH SUCH OFFER OR SOLICITATION IS UNLAWFUL.
NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY SALE MADE HEREUNDER SHALL UNDER
ANY CIRCUMSTANCE CREATE ANY IMPLICATION THAT THE INFORMATION CONTAINED HEREIN IS
CORRECT AS OF ANY DATE SUBSEQUENT TO THE DATE HEREOF.
------------------
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Prospectus Summary.................... 3
Risk Factors.......................... 8
Use of Proceeds....................... 12
Dividend Policy....................... 12
Price Range of Common Stock........... 12
Capitalization........................ 13
Pro Forma Financial Information....... 14
Selected Historical Financial Data.... 19
Management's Discussion and Analysis
of Financial Condition and Results
of Operations....................... 20
Business and Properties............... 25
Management............................ 37
Principal and Selling Stockholders.... 41
Description of Capital Stock.......... 42
Underwriting.......................... 47
Legal Matters......................... 48
Experts............................... 48
Glossary.............................. 49
Available Information................. 51
Incorporation of Certain Documents By
Reference........................... 51
Index to Financial Statements......... F-1
Appendix A -- Summary Report of Lee
Keeling and Associates, Inc......... A-1
</TABLE>
================================================================================
================================================================================
5,795,000 SHARES
COMMON STOCK
[COMSTOCK LOGO]
------------
PROSPECTUS
NOVEMBER 25, 1996
------------
SMITH BARNEY INC.
RAYMOND JAMES
& ASSOCIATES, INC.
BEAR, STEARNS & CO. INC.
OPPENHEIMER & CO., INC.
RODMAN & RENSHAW, INC.
================================================================================
