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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF
[X] THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 1995
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ______ to ______
Commission File No. 0-16741
COMSTOCK RESOURCES, INC.
(Exact name of registrant as specified in its charter)
NEVADA 94-1667468
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
5005 LBJ Freeway, Suite 1000, Dallas, Texas 75244
(Address of principal executive offices including zip code)
(214) 701-2000
(Registrant's telephone number and area code)
Securities registered pursuant to Section 12(b) of the Act: None
Securities registered pursuant to Section 12(g) of the Act:
Common Stock, $.50 Par Value
Preferred Stock Purchase Rights
(Title of class)
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes [X] No
Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K. [X]
As of March 15, 1996, there were 12,956,386 shares of common stock outstanding.
As of March 15, 1996, the aggregate market value of the voting stock held
by non-affiliates of the registrant was approximately $56,400,000 (Such amount
excludes privately held convertible preferred stock which votes on an as
converted basis with common stock.)
DOCUMENTS INCORPORATED BY REFERENCE
The information required by Part III of this report is incorporated by
reference from registrant's definitive proxy statement for its 1996 annual
meeting of stockholders (to be filed with the Securities and Exchange Commission
not later than April 29, 1995).
COMSTOCK RESOURCES, INC.
FORM 10-K
For the Fiscal Year Ended December 31, 1995
CONTENTS
Part I Page
Item 1. Business .................................................. 1
Item 2. Properties ................................................. 15
Item 3. Legal Proceedings........................................... 15
Item 4. Submission of Matters to a Vote of Security Holders......... 15
Part II
Item 5. Market for Registrant's Common Equity and Related
Stockholder Matters................................ 16
Item 6. Selected Historical Financial and Operating Data............ 17
Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations................ 18
Item 8. Financial Statements and Supplementary Data................. 22
Item 9. Changes in and Disagreements with Accountants on
Accounting and Financial Disclosure................ 23
Part III
Item 10. Directors and Executive Officers of the Registrant.......... 24
Item 11. Executive Compensation...................................... 24
Item 12. Security Ownership of Certain Beneficial Owners
and Management......................................... 24
Item 13. Certain Relationships and Related Transactions.............. 24
Part IV
Item 14. Exhibits and Reports on Form 8-K............................ 25
i
PART I
ITEM 1. BUSINESS
General
Comstock Resources, Inc. (together with its subsidiaries, the "Company") is
an independent oil and gas company primarily engaged in the acquisition,
development and production of oil and natural gas properties in the United
States. The Company is also engaged in the purchase, gathering, processing and
marketing of natural gas. The Company believes that its primary strengths are
its ability to add oil and gas reserves at an attractive cost through its oil
and gas property acquisition activities and to successfully operate and further
develop the properties it has acquired with its low operating cost structure.
The Company was originally organized as a Delaware corporation in 1919 under
the name Comstock Tunnel and Drainage Company for the primary purpose of
conducting gold and silver mining operations in and around the Comstock Lode in
Nevada. In 1983, the Company was reincorporated under the laws of the State of
Nevada. In November 1987, the Company changed its name to Comstock Resources,
Inc.
The Company's oil and gas acquisition, development and production operations
are conducted through its wholly owned subsidiaries, Comstock Oil & Gas, Inc.,
Comstock Oil & Gas -- Louisiana, Inc. and Comstock Offshore Energy, Inc. These
companies own working interests in 759 producing oil and gas wells located in
Texas, Louisiana, Oklahoma, Nebraska, Arkansas, Mississippi, Kansas and offshore
Gulf of Mexico. Comstock Management Corporation, a wholly owned subsidiary,
manages the oil and gas properties of Comstock DR II Oil & Gas Acquisition
Limited Partnership for the benefit of certain institutional investors. Comstock
DR II Oil & Gas Acquisition Limited Partnership owns working interests in 118
producing oil and gas wells in Oklahoma, Texas, Kansas, Wyoming and Louisiana.
The Company's natural gas marketing and gathering activities are conducted
through its wholly owned subsidiary, Comstock Natural Gas, Inc. ("CNG"). CNG has
interests in 34 miles of natural gas pipeline in East and South Texas and a gas
processing plant in East Texas. CNG markets approximately 127 million cubic feet
of gas a day for the Company and other natural gas producers. CNG, through its
wholly owned subsidiary Crosstex Pipeline, Inc., serves as managing general
partner and CNG holds a 20.31% limited partner interest in Crosstex Pipeline
Partners, Ltd., which owns 63 miles of natural gas pipeline in East Texas.
Business Strategy
The Company's principal goal is to maximize its value by profitable growth
in oil and gas reserves and production. The Company has been successful in
recent years in achieving this goal primarily through its oil and gas
acquisition program. Over the last five years the Company has added 188 billion
cubic feet ("Bcf") of natural gas and 5.2 million barrels of oil from 15 oil and
gas property acquisitions at a cost of 55 cents per equivalent thousand cubic
feet ("Mcfe") of natural gas, which compares favorably to the industry average.
The Company undertakes workover, recompletion and development drilling
activities to further develop the properties it acquires. The Company's gas
marketing operations allow it to effectively market its natural gas production
at higher prices than it could obtain on a stand alone basis. The Company
maintains an efficient and low cost operating structure which allows it to
operate and develop the properties it acquires with minimal net overhead cost to
the Company. For the year ended December 31, 1995, the Company's net general and
administrative expense, after well operating fee income, was 17 cents per Mcfe
of production.
1
Recent Events
During the first quarter of 1996, the Company entered into agreements to
acquire Black Stone Oil Company and the interests of additional working interest
owners in certain producing oil and gas properties as well as a substantial
interest in undeveloped oil and gas leases located in East Texas for total cash
consideration of approximately $102.9 million (the "Black Stone Acquisition").
Black Stone Oil Company is a privately held company based in Houston, Texas and
is the operator of and owns interests in the oil and gas properties being
acquired. The producing properties to be acquired are located in the Double A
Wells field in Polk County, Texas. The properties are currently producing 5,800
barrels of oil a day and 96,000 Mcf of gas a day (1,800 barrels of oil a day and
29,000 Mcf of gas a day, net to the interests being acquired) from the upper
Woodbine formation at approximately 14,500 feet. The estimated net proved oil
and gas reserves attributable to the interests being acquired are 92 billion
cubic feet of natural gas and 5 million barrels of oil as of January 1, 1996,
the effective date of the acquisition. Such reserves have estimated future net
cash flows of $233 million before income taxes and estimated discounted future
net cash flows before income taxes of $140 million. The acquisition is expected
to close by May 1, 1996 and to be financed under a $175 million credit facility
being provided by the Company's banks. See "Management's Discussion and Analysis
of Financial Condition and Results of Operations-Liquidity."
OIL AND GAS ACQUISITION, DEVELOPMENT AND PRODUCTION
Oil and Gas Property Acquisition Activities
Substantially all of the Company's capital expenditures historically have
related to the acquisition of producing oil and gas properties. The Company
intends to continue its growth strategy emphasizing reserve additions through
its acquisition efforts. The Company may utilize any one or a combination of
borrowings under its bank credit facility, issuance of debt securities or equity
securities, and internally generated cash flow to finance its acquisition
efforts. The Company cannot be assured that sufficient external funds will be
available to fund future acquisitions.
Over the five year period ended December 31, 1995, the Company has completed
15 acquisitions of producing oil and gas properties with an aggregate cost of
$122 million. As a result of these acquisitions, the Company has added 219.6
equivalent Bcf of proved oil and gas reserves as summarized in the following
table:
Acquisition
Acquisition Proved Reserves When Acquired Cost Per
Cost ----------------------------- Mcfe When
Year (000's) (MBbls) (MMcf) (MMcfe) Acquired
---- ------- ------- ------ ------- --------
1991 $ 20,862 689 29,868 34,002 $.61
1992(1) 4,730 44 8,821 9,086 .52
1993(1) 26,928 2,250 28,349 41,848 .64
1994 12,970 388 12,744 15,074 .86
1995 56,081 1,859 108,432 119,585 .47
-------- -------- -------- --------
$121,571 5,230 188,214 219,595 .55
======== ======== ======== ========
(1) 1993 Amounts include $22.7 million as acquisition cost and 962 Mbbls
of oil and 17,782 Mmcf of gas for the acquisition of Stanford Offshore
Energy, Inc. ("Stanford"). The other financial information in this
report reflects the historical operations of Stanford accounted for
under the pooling of interests method. Prior to its acquisition by the
Company, Stanford closed $14.3 of acquisitions in 1993 with reserves of
1,225 Mbbls of oil and 14,550 Mmcf of gas for an acquisition cost per
Mcfe when acquired of $.65. In 1992, Stanford completed an acquisition
for $8.3 million with reserves of 11 Mbbls of oil and 11,883 Mmcf of gas
for an acquisition cost per Mcfe when acquired of $.69.
2
1991 Acquisitions
On June 10, 1991, the Company acquired Tidemark Exploration, Inc. for total
consideration valued at $1.3 million. The Company also assumed $1.4 million in
indebtedness in connection with the acquisition. The acquisition included
interests in 190 wells located primarily in Oklahoma and Arkansas.
On November 7, 1991, the Company acquired interests in 66 producing wells
located in 22 fields in Louisiana, Texas, Oklahoma and Arkansas from Goodrich
Oil Company and certain other working interest owners for cash of approximately
$17.5 million. Major fields purchased in this acquisition include the Ada,
Calhoun and Sugar Creek fields in North Louisiana.
1992 Acquisition
On September 4, 1992, the Company purchased interests in 120 producing wells
located primarily in Oklahoma and Arkansas from Liberty Life Insurance Company.
The Company paid cash of $3.5 million and exchanged $1.6 million in certain
undeveloped oil and gas leases for the properties.
1993 Acquisitions
In January and April 1993, the Company acquired interests in three fields in
Nebraska with ten existing oil and gas wells. The Company issued 490,000 shares
of its common stock for the properties valued at $1.5 million.
During 1993, the Company completed several smaller acquisitions for
properties in South Louisiana and along the Texas Gulf Coast for a total of $1.6
million in cash and shares of common stock.
On November 17, 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 total of 1,760,000 shares of common stock of the Company in
the merger with a total value of $6.2 million. Stanford had interests in 107 oil
and gas wells located in Texas, Offshore Gulf of Mexico, Mississippi, Oklahoma
and Kansas. On the date of the merger, Stanford had approximately $16.5 million
of indebtedness.
Stanford had acquired its oil and gas properties in three significant
acquisitions in 1992 and 1993. On August 31, 1992, Stanford purchased a working
interest in the West Cameron Block 238 field for approximately $8.3 million.
Stanford participated in the acquisition with an unaffiliated oil and gas
company. Stanford acquired a 90% working interest in the property which reduced
to a 45% working interest after Stanford had recovered its adjusted investment.
In February and March 1993, Stanford and Tierra Mineral Development, L.C.
("Tierra") acquired working interests in certain producing oil and gas
properties for $7.5 million. Major properties acquired include interests in the
Mobil David/Chapman Ranch, Mustang Island and East White Point fields located
along the Texas Gulf Coast. Pursuant to the acquisition agreement with Tierra,
the net revenues from these properties were allocated 90% to the Company and 10%
to Tierra until Stanford has recovered its adjusted investment. Thereafter, the
future net revenues were to be allocated 60% to Stanford and 40% to Tierra. On
July 15, 1993, Stanford purchased interests in the Redmond Creek field in South
Texas for approximately $7.4 million.
3
On December 24, 1993, the Company acquired Tierra in exchange for $253,000
in cash and the issuance of 283,350 shares of common stock valued at
approximately $850,000.
1994 Acquisitions
On June 8, 1994, the Company acquired interests in five producing gas wells
in the Vienna field located near the Texas Gulf Coast for $7.3 million in cash.
On July 22, 1994, the Company exchanged one million shares of its newly
issued preferred stock, with a par value of $10 million and an estimated market
value of $8 million, and $10,150,000 cash to repurchase certain production
payments previously conveyed by the Company to a major natural gas company in
November 1991 in connection with the $17.5 million acquisition from Goodrich Oil
Company completed in 1991. The Company had a remaining obligation to deliver
10.7 Bcf of natural gas under a volumetric production payment and had an
obligation to repay $2.5 million under a monetary based production payment.
On September 30, 1994, the Company acquired certain net profits and
overriding royalty interests from MG Trade Finance Corp., the lender under
Stanford's credit facility, for cash of $800,000.
On December 23, 1994, the Company acquired interests in oil and gas
properties together with gas gathering facilities and a gas processing plant
located in the Texas Gulf Coast area for cash of $5.5 million. The oil and gas
properties were acquired for $5 million and included interests in the El Campo
field in Wharton County, Texas.
1995 Acquisitions
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 cash of $8.2 million. The acquisition included interests in the Ship Shoal
Block 66 field, the Main Pass Block 21 field and the Main Pass Block 25 field.
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 from Sonat Inc. for cash of $50.6 million. The Company acquired
interests in 319 oil and gas wells for $49.1 million along with interests in gas
gathering systems for $1.5 million. The acquisition included interests in the
Logansport, Beckville, Waskom, Longwood, Blocker, Simsboro and Hico Knowles
fields in East Texas and North Louisiana.
During 1995, the Company acquired a 74% working interest in the Lake LaRose
field in South Louisiana for approximately $1 million.
1996 Acquisitions
The Company does not have a specific acquisition budget as the timing and
size of acquisitions are difficult to forecast. The Company constantly reviews
acquisition possibilities and anticipates making additional acquisitions in
1996. At the present time the Company has no commitments with respect to any
significant acquisitions, other than for the pending $102.9 million Black Stone
Acquisition.
4
Production
At December 31, 1995, the Company owned producing properties in seven
states, with its proved reserves located primarily in four core areas: East
Texas/North Louisiana, Texas Gulf Coast, Offshore Gulf of Mexico and South
Louisiana. At December 31, 1995, the Company operated 373 producing wells and
also owned non-operated interests in 386 producing wells.
The following table summarizes the Company's proved oil and gas reserves in
its 20 largest fields at December 31, 1995. These fields represent approximately
85% of the Company's proved reserves on such date.
Discounted
Future Net Future Net
Net Oil Net Gas Cash Flows Cash Flows
Field (MBbls) (Bcf) (000s) (000s)
----- ------- ----- ------ ------
EAST TEXAS/NORTH LOUISIANA
Logansport 94 23.5 $ 30,059 $ 16,643
Beckville 176 25.4 32,970 14,581
Waskom 289 19.4 23,421 12,039
Longwood 110 13.2 17,214 9,797
Blocker 66 14.5 17,547 9,628
Ada 13 5.2 9,940 7,082
Sugar Creek 81 6.6 10,905 4,575
Calhoun 32 2.0 4,181 3,446
Simsboro 5 4.0 6,140 3,086
Hico Knowles 57 2.9 4,692 2,977
Other 12 9.0 12,818 5,916
-------- --------- --------- ---------
935 125.7 169,887 89,770
-------- --------- --------- ---------
TEXAS GULF COAST
Vienna - 4.4 7,268 4,666
Mobil David/
Chapman Ranch 161 2.6 5,689 4,079
El Campo 149 2.9 6,155 4,034
Mustang Island 94 3.0 5,383 3,905
East White Point 490 2.7 10,408 3,736
Redmond Creek 148 1.5 4,317 3,247
Other 66 0.7 1,470 779
-------- --------- --------- ---------
1,108 17.8 40,690 24,446
-------- --------- --------- ---------
OFFSHORE GULF OF MEXICO
Ship Shoal 66 410 0.3 6,388 5,348
West Cameron
Block 238 4 4.6 5,941 5,163
Main Pass
Blocks 21/25 513 0.6 5,668 4,256
-------- --------- --------- ---------
927 5.5 17,997 14,767
-------- --------- --------- ---------
SOUTH LOUISIANA
Lake LaRose 38 4.2 8,182 3,920
Other 43 2.5 4,332 2,851
-------- --------- --------- ---------
81 6.7 12,514 6,771
-------- --------- --------- ---------
Other Areas 728 17.5 23,854 12,538
-------- --------- --------- ---------
Total Oil & Gas Reserves 3,779 173.2 $264,942 $148,292
======== ========= ======== =========
5
Logansport. The Company operates 45 wells and owns interests in 18
non-operated wells in the Logansport field area, which includes wells in the
Belle Bower, Canadian Bayou, Grand Cane, Logansport and Spider fields, all of
which are located in DeSoto Parish, Louisiana. The Logansport field area
produces from multiple zones in the Hosston formation. The Company's average
working interest at Logansport in operated wells is 68% and 26% in the
non-operated wells. Daily production from the field net to the Company's
interest is approximately 5,000 Mcf of gas and 26 barrels of oil.
Beckville. The Company operates 47 wells with an average working interest of
51% in the Beckville area. The Company also owns interests in two non-operated
wells with an average working interest of 5%. The Beckville Area includes
properties from several fields - Beckville, Beckville North, Carthage, Oakhill,
and Tatum located in Panola, Rusk, and Harrison Counties, Texas. The predominate
reservoir is the Jurassic aged Cotton Valley. The Cotton Valley can be
subdivided into Upper, Middle, and Lower sand intervals with primary production
coming from the Lower Cotton Valley. Daily production from the Beckville area
net to the Company's interest is approximately 3,000 Mcf of gas and 46 barrels
of oil.
Waskom. The Company has interests in 43 operated wells with an average
working interest of 58% in the Waskom field located in Harrison County, Texas as
well as interests in 41 non-operated wells with an average working interest of
9%. The principal producing zones are Pettit, Travis Peak and Cotton Valley.
Daily production net to the Company's interest is approximately 2,800 Mcf of gas
and 58 barrels of oil.
Longwood. The Company operates 27 wells and has interest in two non-operated
wells in the Longwood field, in Caddo Parish, Louisiana and in Harrison County,
Texas. The Company's average working interest in the operated wells is 73% and
11% in the non-operated wells. The production in Longwood Field is from the
Travis Peak and Hosston formations. Daily production net to the Company's
interest is approximately 1,700 Mcf of gas and 80 barrels of oil.
Blocker. The Company has 18 operated wells with an average working interest
of 87% and two non-operated wells with an average working interest of 64% in the
Blocker field located in Harrison County, Texas. The predominate reservoirs in
this field are the Jurassic aged Cotton Valley sands. Daily production net to
the Company's interest is approximately 2,500 Mcf of gas and 20 barrels of oil.
Ada. The Company has a 35% working interest in the Hamner No. 1 gas unit
located in the Ada field. The Company operates three producing wells in this
unit located in Bienville Parish, Louisiana. The wells produce from the Hosston
A and B formations. Daily production net to the Company's interest is
approximately 3,200 Mcf of gas and 9 barrels of oil.
Sugar Creek. The Company has an average 34% working interest in 14 wells in
the Sugar Creek field in Claiborne Parish, Louisiana. Production ranges from
approximately 4,300 feet to 8,300 feet, with most of the production attributed
to the Kilpatrick Lime, James, Pettit, Hosston and Cotton Valley sands. Daily
production net to the Company's interest is approximately 600 Mcf of gas and 22
barrels of oil.
Calhoun. The Calhoun field is located in Jackson and Ouachita Parish,
Louisiana. The Company has a 24% working interest in three wells in the Calhoun
field producing from the Cadeville sand. Daily production from this field net to
the Company's interest is approximately 1,600 Mcf of gas and 44 barrels of oil.
6
Simsboro. The Company operates four wells in West Simsboro and Simsboro
fields located in Lincoln Parish, Louisiana and has an interest in six
non-operated wells. The primary producing zone is the Hosston formation. The
average working interest in the operated wells is 40%. The average working
interest in the non-operated wells is 8%. Daily production net to the Company's
interest is approximately 1,100 Mcf of gas and 2 barrels of oil.
Hico Knowles. The Company has on average 59% working interest in eight
operated wells and an average 17% working interest in 10 non-operated wells in
the Hico Knowles field in Lincoln Parish, Louisiana. The principal producing
horizons in the Hico Knowles field are the James, Woodruff, Hosston and Cotton
Valley formations. Daily production net to the Company's interest is
approximately 500 Mcf of gas and 13 barrels of oil.
Vienna. The Company owns 100% working interest in four operated wells in the
Vienna field in Lavaca County, Texas. The wells produce from Frio sands at 3,000
feet. Daily production net to the Company's interest is approximately 700 Mcf of
gas and 1 barrel of oil.
Mobil David/Chapman Ranch. The Company owns an average 96% working interest
in three operated wells and an average 41% interest in five non-operated wells
in the Mobil David and Chapman Ranch fields in Nueces County, Texas. The wells
produce from Miocene and Frio sands formation from 5,600 feet to 10,200 feet.
Daily production net to the Company's interest is approximately 800 Mcf of gas
and 16 barrels of oil.
El Campo. The Company owns an average 30% working interest in 11 wells in
the El Campo field in Wharton County, Texas. The wells produce from the Yegua
formation at approximately 10,500 feet. Daily production net to the Company's
interest is approximately 800 Mcf of gas and 78 barrels of oil.
Mustang Island. The Company owns an average 47% working interest in 11 wells
in the Mustang Island field in Nueces County, Texas. The wells produce from
Miocene and Frio sands from approximately 6,500 and 8,500 feet. Daily production
net to the Company's interest is approximately 900 Mcf of gas and 32 barrels of
oil.
East White Point. The Company owns 100% working interest in six operated
wells at East White Point in Nueces Bay off of the Texas Gulf Coast. The wells
produce from Miocene and Frio formation from 1,800 to 11,000 feet. Daily
production net to the Company's interest is approximately 600 Mcf of gas and 1
barrel of oil.
Redmond Creek. The Company owns an average 46% working interest in four
prolific Yegua sand oil and gas wells in Liberty County, Texas. Daily production
net to the Company's interest is approximately 1,100 Mcf of gas and 139 barrels
of oil.
Ship Shoal Block 66. The Company owns a 16% working interest in four wells
in the Ship Shoal Block 66 field located in Terrebonne Parish, Louisiana,
approximately two miles offshore in state waters in the Gulf of Mexico. Daily
production net to the Company's interest is approximately 225 Mcf of gas and 245
barrels of oil.
West Cameron Block 238. The Company owns a 45% working interest in seven
producing offshore gas wells in federal waters in the Gulf of Mexico off the
coast of Louisiana. Daily production net to the Company's interest is
approximately 4,100 Mcf of gas and 8 barrels of oil.
7
Main Pass Blocks 21 and 25. The Company has a 24% working interest in the
Main Pass Block 21 field. The field is located in Louisiana state waters 12
miles east of the Plaquemines Parish, Louisiana shore. There are currently ten
wells producing from formations between 5,000 feet and 8,100 feet. The Company
has a 33% working interest in the Main Pass Block 25 Field located ten miles
east of the Plaquemines Parish, Louisiana shore in a water depth of 12 feet.
There are currently four producing wells in which the Company owns interests.
Daily production in both Main Pass Blocks 21 and 25, net to the Company's
interest, is approximately 400 Mcf of gas and 234 barrels of oil.
Lake LaRose. The Company has a 74% working interest in two wells in this
field located in St. Martin Parish, Louisiana. The wells produce from Frio
(Hackberry) zones at approximately 12,700 feet. The major well in the field is
currently undergoing a workover to correct a down hole problem. Daily production
net to the Company's interest is expected to return to 1,100 Mcf of gas and 15
barrels of oil upon completion of the workover.
Acreage
The following table summarizes the Company's developed and undeveloped
leasehold acreage at December 31, 1995. Excluded is acreage in which the
Company's interest is limited to royalty or similar interests.
Developed Undeveloped
--------------- ---------------
Gross Net Gross Net
----- --- ----- ----
Arkansas 12,313 764 - -
Kansas 2,228 1,709 - -
Louisiana 77,756 57,259 296 48
Mississippi 1,360 210 - -
Nebraska 2,000 1,500 - -
Oklahoma 59,402 24,236 - -
Texas 166,694 124,517 62,916 50,303
Federal Offshore 12,160 5,760 - -
------- ------- ------- --------
Total Acreage 333,913 215,955 63,212 50,351
======= ======= ======= ========
Title
Title to the Company's oil and 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 gas properties are pledged as collateral for the
Company's 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.
8
Recent Drilling Activities
During the three year period ended December 31, 1995, the Company drilled or
participated in the drilling of development and exploratory wells as set forth
in the table below:
Year Ended December 31,
1993 1994 1995
------------------ ---------------- ------------------
Gross Net Gross Net Gross Net
Development Wells:
Oil 14 1.69 - - 2 .48
Gas 2 .44 2 .60 9 2.41
Dry 5 1.19 - - 2 .75
------ ------ ------ ------ ------ ------
21 3.32 2 .60 13 3.64
------ ------ ------ ------ ------ ------
Exploratory Wells:
Oil - - - - - -
Gas - - - - - -
Dry 5 .80 - - - -
------ ------ ------ ------ ------ ------
5 .80 - - - -
------ ------ ------ ------ ------ ------
Total Wells 26 4.12 2 .60 13 3.64
====== ====== ====== ====== ====== ======
Subsequent to December 31, 1995, the Company drilled two gas development
wells (1.02 net wells). One well is currently being completed while the second
well is in the process of drilling.
Producing Well Summary
The following table sets forth the gross and net producing oil and gas wells
in which the Company owned an interest at December 31, 1995, excluding shut in
wells that are awaiting further evaluation or abandonment.
Oil Gas
Gross Net Gross Net
----- --- ----- -----
Arkansas 1 .06 17 1.12
Kansas 3 2.55 1 .83
Louisiana 22 14.14 189 89.58
Mississippi 1 .06 2 .32
Nebraska 7 5.25 4 3.00
Oklahoma 3 .45 117 53.81
Texas 119 56.91 250 157.28
Federal Offshore - - 23 10.35
------ ------ ------ ------
Total Wells 156 79.42 603 316.29
====== ====== ====== ======
Oil and Gas Reserves
The Company's independent petroleum consultants have estimated the proved
reserves of the Company's oil and gas properties as of December 31, 1995, at
173,165,000 Mcf of gas and 3,779,000 barrels of oil. Such reserves have
estimated future net cash flows of approximately $265 million before income
taxes with estimated discounted cash flows, using a 10% discount factor, of
approximately $148 million. The future cash flows have been reduced by
approximately $39 million attributable to future
9
development costs of proved reserves. Proved developed reserves have been
estimated at 130,375,000 Mcf of gas and 2,562,000 barrels of oil. The estimates
of the Company's proved oil and gas reserves were prepared by the independent
reserve engineering firm of Lee Keeling and Associates, Inc.
There are numerous uncertainties inherent in estimating oil and gas reserves
and their values, including many factors beyond the control of the producer. The
reserve data set forth above represents only estimates. Reserve engineering is a
subjective process of estimating underground accumulations of oil and 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 by 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.
In general, the volume of production from oil and 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, or both, the proved reserves of the Company will decline as reserves
are produced. The Company's future oil and gas production is, therefore, highly
dependent upon its level of success in acquiring or developing additional
reserves.
For additional information concerning the discounted future net cash flows
to be derived from these reserves, see Note 14 to the Consolidated Financial
Statements included elsewhere herein.
The Company's estimates of reserves have not been filed with or included in
reports to any federal agency other than the Securities and Exchange Commission.
Volumes, Prices and Lifting Costs
The following table sets forth certain information regarding the Company's
volumes, average prices received, and lifting costs associated with its sales of
oil and gas during each year in the three-year period ended December 31, 1995.
Year Ended December 31,
1993 1994 1995
----------- ---------- -----------
Net Production:
Oil (Bbl) 278,405 262,723 355,520
Gas (Mcf) 8,513,822 6,513,655 9,296,832
Mcfe 10,184,252 8,089,993 11,429,952
Average Sales Prices:
Oil ($/Bbl) $16.22 $15.22 $16.81
Gas ($/Mcf) $ 2.03 $ 1.97 $ 1.73
Average Lifting Costs ($/Mcfe) (1) $ .66 $ .75 $ .65
-------
(1) Includes the cost of labor; repairs and maintenance; material and
supplies; operator overhead charges; insurance; and property,
production and severance taxes.
Markets
General. 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
10
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 of oil and natural gas production and
sales. The oil and gas industry as a whole also competes with other industries
in supplying the energy and fuel requirements of industrial, commercial and
individual consumers.
Oil Sales. 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.
Gas Sales. Substantially all of the Company's gas production is sold on the
spot gas market on a month to month basis at prevailing spot market prices or
sold 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
gas price fluctuations.
Customers
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
gas revenues for 1995.
Competition
The oil and gas industry is highly competitive. Competitors include major
oil companies, other independent oil and gas companies, and individual producers
and operators, many of which have financial resources, staffs and facilities
substantially greater than those of the Company. The Company faces intense
competition for the acquisition of producing oil and gas properties that are
being divested by major and independent oil and gas companies.
Regulation
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 operations are subject to extensive federal, state and local
laws and regulations relating to the generation, storage, handling, emission,
transportation and discharge of materials into the environment. Permits are
required for a variety of the Company's operations, and these permits are
subject to revocation, modification and renewal by issuing authorities.
Governmental authorities have the power to enforce compliance with their
regulations, and violations are subject to fines, injunctions or both. It is
possible that increasingly strict requirements will be imposed by environmental
laws and enforcement policies thereunder. The Company does not anticipate that
it will be required in the near future to expend amounts that are material to
the Company's financial position or results of operations by reason of
environmental laws and regulations. Because such laws and regulations are
frequently changed, the Company is unable to predict the ultimate cost of such
compliance.
The Company believes that the oil and gas industry may experience increasing
liabilities and risks under the Comprehensive Environmental Response,
Compensation and Liability Act, as well as other federal, state and local
environmental laws, as a result of increased enforcement of environmental laws
by various regulatory agencies. As an "owner" or "operator" of property where
hazardous materials may
11
exist or be present, the Company, like all others engaged in the oil and gas
industry, could be liable for the release of any hazardous substances. Although
the Company has not been subject to the imposition of "clean-up" orders by the
government, the potential for sudden and unpredictable liability for
environmental problems is a consideration of increasing importance to the
Company and the oil and gas industry as a whole.
The Company is required to comply with various federal and state regulations
regarding plugging and abandonment of oil and gas wells. The Company provides
reserves for the estimated costs of plugging and abandoning its wells on a unit
of production basis.
NATURAL GAS GATHERING, PROCESSING AND MARKETING
The Company's natural gas gathering, processing and marketing operations are
conducted through its wholly owned gas pipeline and marketing subsidiary,
Comstock Natural Gas, Inc. ("CNG"). CNG was formed in June 1994 to provide
natural gas marketing services to the Company and to small and medium-sized
independent producers on a fee or margin basis. CNG is also involved in the
brokerage of natural gas and in the acquisition, development and operation of
natural gas gathering and processing facilities.
The following table shows CNG's approximate average daily sales volumes for
each quarter of 1995.
Daily Sales
(Mcf)
-----------
First Quarter 96,000
Second Quarter 105,000
Third Quarter 100,000
Fourth Quarter 127,000
Supply
As of December 31, 1995, CNG's supply base was comprised of more than 60
producers representing natural gas production from approximately 650 wells. The
natural gas is marketed and transported on more than 30 intrastate and
interstate pipelines. CNG's average daily natural gas sales volumes transported
by major pipelines are as follows:
Daily Sales
(Mcf)
-----------
Tennessee Gas Pipeline Co. 22,000
Texas Eastern Transmission Corp. 15,000
Lone Star Gas Co. 13,000
ANR Pipeline Co. 7,000
Natural Gas Pipeline Co. of America 7,000
Excluding 26,000 Mcf per day of natural gas marketed by CNG for the Company,
which represents approximately 20% of the total volume marketed by CNG, no one
producer accounted for more than 10% of CNG's natural gas supply.
12
Sales
During 1995, approximately 93% of CNG's gas marketing sales were to
independent and pipeline affiliated marketing companies. The remaining volumes
were sold to local distribution companies and industrial end users. During 1995,
sales to MG Natural Gas Company, an independent marketing company, accounted for
approximately 18% of CNG's gas marketing sales. No other customer accounted for
more than 10% of CNG's gas marketing sales.
Gas Gathering and Processing
As of December 31, 1995, CNG owned interests in five wellhead natural gas
gathering systems and a natural gas processing plant located in East and South
Texas. The five wellhead natural gas gathering systems include 34 miles of
pipeline and have a throughput capacity of approximately 60 million cubic feet a
day. Current throughput is approximately 10 million cubic feet a day. Natural
gas gathering is performed by CNG for a fee based on volume transported. CNG has
a 40% interest in a refrigerated lean oil gas processing plant in East Texas
with a capacity of 25 million cubic feet per day. The plant is currently
operating at capacity. An expansion of the plant is in progress which will
increase plant capacity to approximately 50 million cubic feet per day. Plant
throughput upon completion of expansion is projected to be 45 million cubic feet
per day.
CNG also owns the managing general partner interest and a 20.31% limited
partner interest in Crosstex Pipeline Partners, Ltd. ("Crosstex"). Crosstex owns
five gathering systems consisting of 63 miles of natural gas pipeline located in
East Texas. The systems serve 126 wells and have a capacity of 65,000 Mcf per
day and a current throughput of 21,000 Mcf per day.
Competition
The deregulation of natural gas has led to the emergence of over 300
marketing companies in the United States and intense competition for the
brokerage of natural gas between producers and consumers. Competitors include
major integrated oil and gas companies, independent and pipeline affiliated
marketing companies, and regional natural gas gatherers, brokers and marketers
of varying sizes. Many of the competitors have capital resources significantly
greater than that of CNG's and control substantially greater supplies of natural
gas than CNG.
Regulation
CNG's natural gas marketing activities are not regulated by the Federal
Energy Regulatory Commission ("FERC") or any state public utility commissions.
CNG's marketing activities and the revenues it receives under sales agreements
are affected by regulatory events and competitive forces in the natural gas
markets. Through the issuance of Orders 436, 500 and 636, FERC is endeavoring to
increase competition in natural gas markets by eliminating or changing many of
the procedures associated with the interstate pipelines' traditional role as
wholesale merchants of natural gas in order that all natural gas suppliers will
have a full and fair opportunity to compete in all markets. The Company cannot
predict what ultimate effect the FERC orders will have on its marketing
activities.
13
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 four production offices and yard facilities
in Marshall, Bay City and Dumas, Texas and in Woodward, Oklahoma.
EXECUTIVE OFFICERS OF THE COMPANY
The following table sets forth certain information as of March 15, 1996
concerning the executive officers of the Company.
Served As
An Officer
Name Age Since Position with Company
---- --- ----- ---------------------
M. Jay Allison 40 1987 President, Chief Executive Officer
and Director
Roland O. Burns 36 1990 Senior Vice President, Chief
Financial Officer, Secretary and
Treasurer
James L. Menke 44 1994 Vice President of Operations
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. Mr. Allison, in 1983, 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 is serving on the Board of Trustees of
Howard Payne University in Brownwood, Texas.
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 a Masters
and a Bachelors degree of Accountancy from the University of Mississippi in 1982
and is a Certified Public Accountant in the State of Texas.
James L. Menke has been Vice President of Operations of the Company since
April 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 in
the State of Texas.
14
Messrs. Allison and Burns each have one year employment agreements in their
current positions with the Company which expire June 30, 1996, unless earlier
terminated for good cause. Subject to such employment agreements, officers are
elected annually by the Board of Directors of the Company and may be removed at
any time by the Board of Directors. There are no family relationships among the
executive officers and there are no other arrangements or understandings
pursuant to which any of them were elected as officers.
EMPLOYEES
At December 31, 1995, the Company had 54 employees and utilized contract
employees for certain of its oil field operations. The Company considers its
employee relations to be satisfactory.
ITEM 2. PROPERTIES
See Item 1 "Business" for the required disclosures concerning the Company's
properties.
ITEM 3. 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.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matters were submitted to a vote of the Company's security holders during
the fourth quarter of 1995.
15
PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED
STOCKHOLDER MATTERS
The Company's common stock is listed for trading on the Nasdaq National
Market tier of the Nasdaq Stock Market under the symbol "CMRE." The following
table sets forth, on a per share basis for the periods indicated, the high and
low sales prices, closing price and total volume by calendar quarter for the
periods indicated as reported by the Nasdaq Stock Market. Such prices represent
inter-dealer prices without retail markup, markdown, or commission.
Volume
High Low Close (000s)
---- --- ----- ------
1994 - First Quarter $5.75 $3.00 $3.56 11,799
Second Quarter 4.25 2.94 3.81 6,348
Third Quarter 4.56 3.00 3.34 4,895
Fourth Quarter 3.62 2.81 3.31 3,890
1995 - First Quarter 3.69 2.75 3.50 4,833
Second Quarter 4.94 3.38 3.94 9,614
Third Quarter 4.88 3.75 4.38 6,518
Fourth Quarter 5.63 4.00 5.63 7,179
As of March 15, 1996, the Company had 12,956,386 shares of common stock
outstanding, which were held by 1,772 holders of record and approximately 2,000
beneficial owners who maintain their shares in "street name" accounts.
The Company has never paid cash dividends on its common stock. The Company
presently intends to retain any earnings for the operation and expansion of its
business and does not anticipate paying cash dividends in the foreseeable
future. Any future determination as to the payment of dividends will depend upon
results of operations, capital requirements, the financial condition of the
Company and such other factors as the Board of Directors of the Company may deem
relevant. In addition, the Company is limited under its bank credit agreement
and the provisions of its several outstanding preferred stock series from paying
or declaring cash dividends.
16
ITEM 6. SELECTED HISTORICAL FINANCIAL AND OPERATING DATA
The historical financial data presented in the table below for and at the
end of each of the years in the five-year period ended December 31, 1995 are
derived from the Consolidated Financial Statements of the Company. The data
presented below should be read in conjunction with the Company's Consolidated
Financial Statements and the notes thereto included elsewhere herein and
"Management's Discussion and Analysis of Financial Condition and Results of
Operations."
Year Ended December 31,
1991 1992 1993 1994 1995
---- ---- ---- ---- -----
($ in thousands, except per share data)
INCOME STATEMENT DATA (a):
Revenues:
Oil and gas sales $ 2,710 $ 10,680 $21,805 $16,855 $22,091
Gas marketing - - - 14,957 50,078
Gas gathering and processing 153 213 107 72 600
Gain on sales of property 106 - 111 328 2,608
Other income 160 220 430 442 291
------ ------ ------ ------ ------
3,129 11,113 22,453 32,654 75,668
------ ------ ------ ------ ------
Costs and expenses:
Lease operating (b) 1,572 3,150 6,673 6,099 7,427
Gas marketing - - - 14,521 48,909
Gas gathering and processing 120 159 91 11 209
General and administrative, net 2,089 1,485 1,834 1,823 1,979
Depreciation, depletion and
amortization 1,758 3,759 8,334 7,390 8,613
Impairment of oil and
gas properties - - - - 29,150
Interest 449 1,037 2,184 2,869 5,542
Other expenses 701 - 423 - -
------- ------ ------ ------ --------
6,689 9,590 19,539 32,713 101,829
Income (loss) before
income taxes (3,560) 1,523 2,914 (59) (26,161)
Provision for income taxes - - - - -
------- ------ ------ ------ --------
Income (loss) before
extraordinary items (3,560) 1,523 2,914 (59) (26,161)
Preferred stock dividends - (56) (173) (818) (1,908)
------- ------ ------ ------ --------
Net income (loss) attributable
to common stock (3,560) 1,467 2,741 (877) (28,069)
Extraordinary loss - - (417) (615) -
------- ------ ------ ------ --------
Net income (loss) $(3,560) $1,467 $2,324 $(1,492) $(28,069)
======= ====== ====== ====== ========
Weighted average common
shares outstanding 7,006 8,180 10,762 12,065 12,546
Earnings Per Share:
Net income (loss) before
extraordinary items $ (.51) $ .18 $ .25 $ (.07) $ (2.24)
Net income (loss) after
extraordinary items (.51) .18 .22 (.12) (2.24)
Cash Flow Data:
Cash provided (used) by:
Operating activities $ (583) $(1,020) $16,488 $ 7,376 $ 8,407
Investing activities (18,110) (12,472) (17,415) (23,972) (58,725)
Financing activities 19,809 12,910 790 19,266 48,809
BALANCE SHEET DATA (end of period):
Property and equipment, net $44,784 $53,474 $66,068 $77,989 $102,116
Total assets 51,944 66,185 74,095 91,571 120,099
Total debt 7,843 19,164 21,930 37,932 71,811
Stockholders' equity 18,850 23,110 27,646 41,205 30,128
17
Year Ended December 31,
1991 1992 1993 1994 1995
---- ---- ---- ---- ----
($ in thousands, except per share data)
SELECTED OPERATING DATA: (a)
Production:
Oil (MBbls) 86 131 278 263 356
Gas (MMcf) 721 4,387 8,514 6,514 9,297
Gas equivalent (MMcfe) 1,235 5,171 10,184 8,090 11,430
Average sales prices:
Oil (per Bbl) $20.38 $19.22 $16.22 $15.22 $16.81
Gas (per Mcf) 1.28 1.86 2.03 1.97 1.73
Production costs (per Mcfe) (b) 1.27 .61 .66 .75 .65
Proved reserves (end of period):
Oil (MBbls) 3,022 2,259 6,111 5,119 3,779
Gas (MMcf) 77,733 76,061 74,363 92,840 173,165
Total proved reserves (MMcfe) 95,864 89,618 111,028 123,554 195,840
Proved developed reserves(MMcfe) 24,349 37,092 52,838 71,851 145,750
Annual reserve replacement
ratio (c) (9.5) .9 3.4 2.5 7.3
Estimated reserve
life (in years) (d) 77.6 17.3 10.9 15.3 17.1
Present value of estimated future
net revenues before income
taxes (discounted at 10%) $53,627 $45,447 $ 60,952 $78,744 $148,292
Standardized measure of
discounted future net
cash flows 36,388 45,335 60,757 78,481 146,506
- --------
(a)Significant acquisitions of producing oil and gas properties affect the
comparability of the historical financial and operating data for the periods
presented above.
(b)Includes lease operating costs and production and ad valorem taxes.
(c)The annual reserve replacement ratio is a percentage determined on an Mcfe
basis by dividing the estimated reserves added during a year from
acquisitions of proved reserves, extensions, discoveries and revisions of
previous estimates, excluding property sales, by the oil and gas produced
during that year.
(d)Estimated reserve life is calculated on a Mcfe basis by dividing the total
estimated proved reserves at year-end by the total production during the
year.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
Results of Operations
The Company's results of operations have been significantly impacted by its
success in acquiring producing oil and gas properties. Fluctuations in oil and
gas prices have also significantly affected the Company's financial results.
Relatively minor changes in natural gas prices can significantly impact the
Company's results of operations and cash flow and could significantly impact the
Company's borrowing base under its bank credit facility. Based on the 1995
operating results, a change in the average natural gas price realized by the
Company of 10 cents per Mcf would result in a change in net income and cash flow
of approximately $879,000 or 7 cents per share.
18
The following table reflects the Company's oil and gas production and its
average oil and gas prices for the periods presented:
Years Ended December 31,
1993 1994 1995
PRODUCTION:
Oil (MBbls) 278 263 356
Gas (MMcf) 8,514 6,514 9,297
AVERAGE PRICES:
Oil (per Bbl) $16.22 $15.22 $16.81
Gas (per Mcf) $ 2.03 $ 1.97 $ 1.73
Average oil and gas prices received by the Company fluctuate generally with
changes in the posted prices for oil and spot market prices for gas. The
Company's average gas price for 1995 was 12 percent below the same period in
1994, due primarily to the decline in the average spot market prices for gas.
The Company achieved a 6 percent higher gas price in 1995 due to a natural gas
price swap agreement which the Company utilized to hedge 25 percent of its 1995
natural gas production. The Company experienced a 10 percent increase in its
average oil price in 1995 compared to the same period in 1994. The Company
experienced a 3 percent decrease in its average gas price and a 6 percent
decrease in its average oil price in 1994 compared to 1993.
In 1996, the Company to date has entered into positions to hedge 2,905,000
MMBtu of its 1996 gas production at an average price of $1.90 per Mmbtu. The
Company has included delivery point basis adjustments in its 1996 gas price swap
agreements.
Year to Year Comparisons
Year Ended December 31, 1995 Compared to Year Ended December 31, 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 adoption of a new
accounting standard in the fourth quarter of 1995. The Company recorded an
impairment of its oil and gas properties of $29.2 million relating to the
adoption of Statement of Financial Accounting Standards No. 121, "Accounting for
the Impairment of Long-Lived Assets and Long-Lived Assets to be Disposed of."
The 1995 results also include a $2.6 million gain from the sale of a gas
processing plant for $3 million in 1995.
Oil and gas sales increased $5.2 million (31 percent), to $22.1 million in
1995 from $16.9 million in 1994 due primarily to a 43 percent increase in gas
production and a 35 percent increase in oil production. The production increases
related primarily to production from certain oil and gas property acquisitions
completed in late 1994 and in 1995. The production increases were partially
offset by a 12 percent decrease in the Company's average gas price. The
Company's average oil price for the period increased by 10 percent.
19
Gas marketing net margins (revenues less expenses) increased $733,000 (168
percent) to $1,170,000 in 1995 from $437,000 in 1994 due primarily to a full
year of gas marketing operations in 1995 as compared to only seven months of
operations in 1994. The average margin per Mcf sold was $.032 in 1995 as
compared to $.041 in 1994.
Gas gathering and processing net margins (revenues less expenses) increased
$329,000 (536 percent) 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.
Other income decreased $152,000 (34 percent) to $290,000 in 1995 from
$442,000 in 1994.
Lease operating expenses, including production taxes, increased $1.3 million
(22 percent) to $7.4 million in 1995 from $6.1 million in 1994 due primarily to
the 41 percent increase in oil and gas production (on an equivalent Mcf basis)
resulting from the property acquisitions previously discussed. Lease operating
expenses per Mcfe produced decreased 15 percent to $.65 in 1995 from $.75 in
1994.
General and administrative expenses increased $156,000 (9 percent) to $2
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.
Depreciation, depletion and amortization increased $1.2 million (17 percent)
to $8.6 million in 1995 from $7.4 million in 1994 due primarily to the 41
percent increase in oil and gas production (on an equivalent Mcf basis).
Amortization per Mcfe produced decreased 18 percent to $.72 in 1995 from $.88 in
1994.
Interest expense increased $2.7 million (93 percent) 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 bank credit facility and an increase in
interest rates. The average annual interest rate paid under the bank credit
facility was 10.5 percent in 1995 as compared to 8.6 percent in 1994.
Year Ended December 31, 1994 Compared to Year Ended December 31, 1993
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. A decrease in the
Company's oil and gas production of 21 percent (on an equivalent Mcf basis)
accounted for the decline in earnings. The production decrease was related to a
reduction in the Company's ownership interest in the West Cameron Block 238
field from 90 percent in 1993 to 45 percent in 1994.
Oil and gas sales decreased $4.9 million (23 percent), to $16.9 million in
1994 from $21.8 million in 1993 due primarily to a 23 percent decrease in gas
production. Oil production increased 6 percent in 1994. Sales were also impacted
by a 3 percent decrease in gas prices and a 6 percent decrease in oil prices.
The gas production decline related primarily to the decrease in the ownership
interest in the West Cameron property to 45 percent from 90 percent.
Gas marketing net margins (revenues less expenses) reported in 1994 were
$437,000 which related to the commencement of gas marketing operations by the
Company in June 1994. The average margin per Mcf sold was $.041 in 1994.
20
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.
Other income increased $13,000 (3 percent) to $442,000 in 1994 from $430,000
in 1993.
Lease operating expenses, including production taxes, decreased $575,000 (9
percent) to $6.1 million in 1994 from $6.7 million in 1993 due primarily to the
21 percent decrease in oil and gas production (on an equivalent Mcf basis) as
discussed above. Lease operating expenses per equivalent Mcf produced increased
14 percent to $.75 in 1994 from $.66 in 1993.
General and administrative expenses of $1.8 million in 1994 were comparable
to general and administrative expenses in 1993.
Depreciation, depletion and amortization decreased $900,000 (11 percent) to
$7.4 million in 1994 from $8.3 million 1993 due primarily to the 21 percent
decrease in oil and gas production (on an equivalent Mcf basis). Amortization
per Mcfe produced increased 13 percent to $.88 in 1994 as compared to $.78 in
1993.
Interest expense increased $686,000 (31 percent) 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.
Capital Expenditures
The Company's annual capital expenditure activity for the last three years
is summarized as follows (in thousands):
Year Ended December 31,
1993 1994 1995
---- ---- ----
Acquisition of oil and
gas reserves $18,500 $12,970 $56,081
Other leasehold costs 350 607 12
Workovers and recompletions 1,066 1,271 2,152
Development drilling 1,324 218 1,514
Exploratory drilling 424 - -
Acquisition of gas marketing,
processing and
gathering assets - 1,098 2,008
Other 115 222 42
------- ------- -------
Total $21,779 $16,386 $61,809
The timing of most of the Company's capital expenditures is discretionary
with no material long-term capital expenditure commitments, except for the
pending Black Stone Acquisition. Consequently, the Company has a significant
degree of flexibility to adjust the level of such expenditures as circumstances
warrant. The Company uses borrowings under its bank credit facility as well as
internally generated cash flow to fund capital expenditures other than
significant acquisitions and anticipates that such sources will be sufficient to
fund its planned $12 million in developmental capital expenditures during 1996.
The Company does not have a specific acquisition budget since the timing and
size of acquisitions are difficult to predict. In addition to the pending Black
Stone Acquisition, the Company is actively pursuing additional acquisitions of
oil and gas properties.
21
Liquidity
Under its credit agreement with NBD Bank, N.A. and Bank One, Texas, N.A.,
the Company has available a revolving credit facility (the "Bank Credit
Facility"). The Bank Credit Facility establishes a borrowing base ($65.8 million
at December 31, 1995) determined by the banks' evaluation of the Company's oil
and gas reserves. Outstanding advances under the Bank Credit Facility cannot
exceed the borrowing base and bear interest, payable monthly, at a floating rate
based on the agent bank's prime rate plus 1 1/2%. In addition, the Company must
pay a commitment fee of one half percent per annum on the unused portion of the
banks' commitment. The unused portion of the Bank Credit Facility was
approximately $4.2 million at December 31, 1995. In addition to the Bank Credit
Facility, the banks have provided a $10 million term loan that matures on July
31, 1996. Amounts outstanding under the term loan bear interest, payable
monthly, at a floating rate based on the agent's prime rate plus 4%.
In June 1995, the Company sold 1,500,000 shares of its Series 1995
Convertible Preferred Stock, $10 par value, for $15 million in a private
placement. Proceeds were used to fund $10 million of the Company's $50.6 million
acquisition of oil and gas properties and gas gathering assets from Sonat Inc.
in July 1995 with $5 million to be used toward the development of the Company's
oil and gas properties.
Internally generated cash flow and the borrowing capacity under the Bank
Credit Facility are the Company's major sources of liquidity. At December 31,
1995 the Company had a working capital deficit of approximately $17.9 million
due primarily to $18.7 million in current maturities of long-term debt
outstanding as of December 31, 1995.
The Company has received a commitment to refinance its existing bank term
note and amounts outstanding under the Bank Credit Facility as part of a $175
million credit facility being provided in conjunction with the closing of the
pending Black Stone Acquisition. The commitment is contingent on the closing of
the pending Black Stone Acquisition and there are no assurances that the
acquisition will be consummated. Accordingly, the Company may use other sources
of capital, including the issuance of additional debt securities or equity
securities, to fund any major acquisitions it might secure in the future and to
repay the existing bank debt including the $10 million bank term note.
Inflation
In recent years inflation has not had a significant impact on the Company's
operations or financial condition.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
See Part IV, Item 14.(a)(i) and (ii) for information required for this item.
Management Responsibility for Financial Statements. The financial statements
have been prepared by the management of the Company in conformity with generally
accepted accounting principles. Management is responsible for the fairness and
reliability of the financial statements and other financial data included in
this report. In the preparation of the financial statements, it is necessary to
make informed estimates and judgments based on currently available information
on the effects of certain events and transactions.
22
The Company maintains accounting and other controls which management
believes provide reasonable assurance that financial records are reliable,
assets are safeguarded, and that transactions are properly recorded in
accordance with management's authorizations. However, limitations exist in any
system of internal control based upon the recognition that the cost of the
system should not exceed benefits derived.
The Company's independent public accountants, Arthur Andersen LLP, are
engaged to audit the financial statements of the Company and to express an
opinion thereon. Their audit is conducted in accordance with generally accepted
auditing standards to enable them to report whether the financial statements
present fairly, in all material respects, the financial position and results of
operations of the Company in accordance with generally accepted accounting
principles.
The Audit Committee of the Board of Directors of the Company, composed of
three directors who are not employees, meets periodically with the independent
public accountants and management. The independent public accountants have full
and free access to the Audit Committee to meet, with and without management
being present, to discuss the results of their audits and the quality of
financial reporting.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING
AND FINANCIAL DISCLOSURE
Not applicable.
23
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required by this item is incorporated herein by reference to
the Company's definitive proxy statement which will be filed with the Securities
and Exchange Commission within 120 days after December 31, 1995.
ITEM 11. EXECUTIVE COMPENSATION
The information required by this item is incorporated herein by reference to
the Company's definitive proxy statement which will be filed with the Securities
and Exchange Commission within 120 days after December 31, 1995.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
MANAGEMENT
The information required by this item is incorporated herein by reference to
the Company's definitive proxy statement which will be filed with the Securities
and Exchange Commission within 120 days after December 31, 1995.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item is incorporated herein by reference to
the Company's definitive proxy statement which will be filed with the Securities
and Exchange Commission within 120 days after December 31, 1995.
24
PART IV
ITEM 14. EXHIBITS AND REPORTS ON FORM 8-K
(a) Following are documents filed as part of this Report:
(i)CONSOLIDATED FINANCIAL STATEMENTS OF COMSTOCK
RESOURCES, INC. AND SUBSIDIARIES.
F-1 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
(ii) EXHIBITS.
Exhibit
Number Exhibit
2.1 - Agreement and Plan of Reorganization by and among the Company, Comstock
Acquisition, Inc. and Stanford Offshore Energy, Inc. and the
Shareholders of Stanford Offshore Energy, Inc. (incorporated herein by
reference to Exhibit 2 to the Company's Current Report on Form 8-K
dated November 17, 1993, as amended by Form 8 dated January 14, 1994
and Form 8-K/A dated March 29, 1994).
2.2 - Purchase and Sale Agreement, dated May 16, 1995 between Comstock
Resources, Inc. and Sonat Exploration Company (incorporated herein by
reference to Exhibit 2(a) to Company's Current Report on Form 8-K dated
May 16, 1995).
3.1* - Restated Articles of Incorporation of the Company.
3.2 - Bylaws of the Company as adopted on July 16, 1990 (incorporated herein
by reference to Exhibit 3.7 to Company's Annual Report on Form 10-K for
the fiscal year ended December 31, 1990).
4.1 - Certificate of Designation, Preferences and Rights of Series A Junior
Participating Preferred Stock dated December 6, 1990 (incorporated
herein by reference to Exhibit 3.6 to the Company's Annual Report on
Form 10-K for the fiscal year ended December 31, 1990).
25
Exhibit
Number Exhibit
4.2 - Certificate of Voting Powers, Designations, Preferences, and Relative,
Participating, Optional or Other Special Rights of the Series 1994
Convertible Preferred Stock (incorporated herein by reference to
Exhibit 3(a) to the Company's Current Report on Form 8-K dated January
7, 1994).
4.3 - Certificate of Voting Powers, Designations, Preferences, and Relative,
Participating, Optional or Other Special Rights of the 1994 Series B
Convertible Preferred Stock (incorporated herein by reference to
Exhibit 3(a) to the Company's Current Report on Form 8-K dated July 22,
1994).
4.4 - Certificate of Voting Powers, Designations, Preferences, and Relative,
Participating, Optional or Other Special Rights of the Series 1995
Convertible Preferred Stock (incorporated herein by reference to
Exhibit 3(a) to the Company's Current Report on Form 8-K dated June 19,
1995).
4.5 - Rights Agreement, dated as of December 10, 1990, by and between the
Company and Society National Bank (successor to Ameritrust Texas N.A.),
as Rights Agent, (incorporated herein by reference to Exhibit 1 to
Company's Registration Statement on Form 8-A, dated December 14, 1990).
4.6 - First Amendment to the Rights Agreement, by and between the Company and
Society National Bank (successor to Ameritrust Texas, N.A.), as Rights
Agent, dated January 7, 1994 (incorporated herein by reference to
Exhibit 3.6 to the Company's Annual Report on Form 10-K for the fiscal
year ended December 31, 1993).
4.7* - Second Amendment to the Rights Agreement, by and between the Company
and Bank One, Texas N.A. (successor to Society National Bank), as
Rights Agent, dated April 1, 1995.
4.8* - Third Amendment to the Rights Agreement, by and between the Company and
Bank One, Texas N.A., as Rights Agent, dated June 16, 1995.
4.9* - Fourth Amendment to the Rights Agreement, by and between the Company
and American Stock Transfer and Trust Company (successor to Bank One,
Texas N.A.), as Rights Agent, dated September 1, 1995.
10.1 - Credit Agreement, dated as of July 31, 1995, between the Company, NBD
Bank, N.A., Bank One Texas N.A. and NBD Bank, N.A., as agent
(incorporated herein by reference to Exhibit 99(c) to the Company's
Current Report on Form 8-K dated May 16, 1995, as amended by Form 8-K/A
dated August 4, 1995).
26
Exhibit
Number Exhibit
10.2* - Amendment No. 1 to the Credit Agreement effective December 31, 1995,
between the Company, NBD Bank, N.A., Bank One, Texas N.A. and NBD Bank,
N.A., as agent.
10.3*# - Employment Agreement, dated July 1, 1995, by and between the Company
and M. Jay Allison.
10.4*# - Employment Agreement, dated July 1, 1995, by and between the Company
and Roland O. Burns.
10.5 # - Comstock Resources, Inc. 1991 Long-term Incentive Plan, dated as of
April 1, 1991 (incorporated herein by reference to Exhibit 10.8 to the
Company's Annual Report on Form 10-K for the fiscal year ended December
31, 1991).
10.6 # - Form of Nonqualified Stock Option Agreement, dated April 2, 1991,
between the Company and certain officers and directors of the Company
(incorporated herein by reference to Exhibit 10.9 to the Company's
Annual Report on Form 10-K dated December 31, 1991).
10.7 # - Form of Restricted Stock Agreement, dated April 2, 1991, between the
Company and certain officers of the Company (incorporated herein by
reference to Exhibit 10.10 to the Company's Annual Report on Form 10-K
dated December 31, 1991).
10.8 - Stock Purchase Warrant Agreement, (W-1), dated as of May 22, 1991 by
and between the Company and Liberty Life Insurance Company
(incorporated herein by reference to Exhibit 10.21 to the Company's
Annual Report on Form 10-K dated December 31, 1991).
10.9 - Warrant Modification Agreement, (W-1), dated April 8, 1992, by and
between the Company and Liberty Life Insurance Company (incorporated
herein by reference to Exhibit 10.18 to the Company's Annual Report on
Form 10-K dated December 31, 1992).
10.10 - Stock Purchase Warrant Agreement, (W-2), dated May 22, 1991, by and
between the Company and Liberty Life Insurance Company (incorporated
herein by reference to Exhibit 10.22 to the Company's Annual Report on
Form 10-K dated December 31, 1991).
10.11 - Warrant Modification Agreement, (W-2), dated April 8, 1992, by and
between the Company and Liberty Life Insurance Company (incorporated
herein by reference to Exhibit 10.20 to the Company's Annual Report on
Form 10-K dated December 31, 1992).
27
Exhibit
Number Exhibit
10.12 - Stock Purchase Warrant Agreement, (W-3), dated April 8, 1992, by and
between the Company and Liberty Life Insurance Company (incorporated
herein by reference to Exhibit 10.21 to the Company's Annual Report on
Form 10-K dated December 31, 1992).
10.13 - Form of Stock Option Agreement, dated October 12, 1994 by and between
the Company and Christopher T. H. Pell, et al (incorporated herein by
reference to Exhibit 10.18 to the Company's Annual Report on Form 10-K
dated December 31, 1994).
10.14 - Lease Agreement, dated as of December 20, 1994, by and between the
Company and Occidental Tower Corporation (incorporated herein by
reference to Exhibit 10.19 to the Company's Annual Report on Form 10-K
dated December 31, 1994).
21* - Subsidiaries of the Company.
23* - Consent of Independent Public Accountants.
27* - Financial Data Schedule.
- ----------
* Filed herewith.
# Management contract or compensatory plan document.
(b) Reports on Form 8-K:
Form 8-K Report filed subsequent to September 30, 1995 are as follows:
Date Item Description
January 22, 1996 5 Letter of Intent to Acquire Black Stone Oil Company
Properties
28
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934, the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
COMSTOCK RESOURCES, INC.
By: /s/M. JAY ALLISON
M. Jay Allison
President and Chief Executive Officer
(Principal Executive Officer)
Date: March 15, 1996
Pursuant to the requirements of the Securities Exchange Act of 1934, this
report has been signed below by the following persons on behalf of the
registrant and in the capacities and on the dates indicated.
/s/M. JAY ALLISON President, Chief Executive Officer and March 15, 1996
M. Jay Allison Director (Principal Executive Officer)
/s/ROLAND O. BURNS Senior Vice President, Chief Financial March 15, 1996
- ----------------------
Roland O. Burns Officer, Secretary and Treasurer
(Principal Financial and Accounting Officer)
Majority of Board of Directors:
/s/HAROLD R. LOGAN Chairman of the Board of Directors March 15, 1996
- ----------------------
Harold R. Logan
/s/RICHARD S. HICKOK Director March 15, 1996
- ----------------------
Richard S. Hickok
/s/FRANKLIN B. LEONARD Director March 15, 1996
- ----------------------
Franklin B. Leonard
/s/CECIL E. MARTIN, JR. Director March 15, 1996
- -----------------------
Cecil E. Martin, Jr.
/s/HERBERT C. PELL, III Director March 15, 1996
- ------------------------
Herbert C. Pell, III
29
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-1
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
December 31,
---------------------------
1994 1995
------------- -------------
Cash and Cash Equivalents $ 3,425,248 $ 1,916,648
Accounts Receivable:
Oil and gas sales 2,616,086 5,385,000
Gas marketing sales 5,558,418 8,450,794
Joint interest operations 619,063 1,230,403
Prepaid Expenses and Other 250,397 172,093
Inventory 93,728 92,139
------------- -------------
Total current assets 12,562,940 17,247,077
------------- -------------
Property and Equipment:
Oil and gas properties,
successful efforts method 113,269,341 154,843,663
Other 1,371,517 2,717,625
Accumulated depreciation, depletion
and amortization (36,651,750) (55,445,097)
------------- -------------
Net property and equipment 77,989,108 102,116,191
------------- -------------
Other Assets 1,018,665 735,398
------------- -------------
$ 91,570,713 $120,098,666
============= =============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Portion of Long-term Debt $ 7,009,864 $ 18,677,181
Accounts Payable and Accrued Expenses 8,368,639 10,977,435
Accrued Natural Gas Purchases 3,120,114 5,533,784
------------- -------------
Total current liabilities 18,498,617 35,188,400
------------- -------------
Long-term Debt, less current portion 30,922,479 53,133,751
Deferred Revenue - 430,000
Other Noncurrent Liabilities 944,860 1,218,742
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. 16,000,000 31,000,000
Common stock - $.50 par, 30,000,000 shares
authorized, 12,342,811 and 12,926,672
shares outstanding at December 31, 1994 and 6,171,406 6,463,336
1995, respectively.
Additional paid-in capital 36,523,602 38,182,398
Retained deficit (17,375,095) (45,444,055)
Less: Deferred compensation -
restricted stock grants (115,156) (73,906)
------------- -------------
Total stockholders' equity 41,204,757 30,127,773
------------- -------------
$ 91,570,713 $120,098,666
============= =============
The accompanying notes are an integral part of these statements.
F-2
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
For the Year Ended December 31,
------------- ------------- -------------
1993 1994 1995
------------- ------------- -------------
Revenues:
Oil and gas sales $ 21,804,502 $ 16,854,665 $ 22,090,894
Gas marketing sales - 14,957,760 50,078,366
Gas gathering and processing 107,321 71,983 600,212
Gain on sales of property 111,605 327,760 2,608,088
Other income 429,622 442,286 290,115
------------- ------------- -------------
Total revenues 22,453,050 32,654,454 75,667,675
------------- ------------- -------------
Expenses:
Oil and gas operating 6,673,494 6,098,972 7,426,626
Natural gas purchases - 14,521,066 48,908,969
Gas gathering and processing 90,541 10,548 209,535
Exploration 423,600 - -
Depreciation, depletion and amortization 8,333,727 7,389,847 8,613,042
General and administrative, net 1,833,622 1,823,543 1,979,283
Interest 2,183,803 2,869,455 5,541,680
Impairment of oil and gas properties - - 29,150,000
------------- ------------- -------------
Total expenses 19,538,787 32,713,431 101,829,135
------------- ------------- -------------
Income (loss) before income taxes and
extraordinary item 2,914,263 (58,977) (26,161,460)
Provision for income taxes - - -
------------- ------------- -------------
Income (loss) before extraordinary item 2,914,263 (58,977) (26,161,460)
Preferred stock dividends (172,500) (817,610) (1,907,500)
------------- ------------- -------------
Net income (loss) attributable to common
stock before extraordinary item 2,741,763 (876,587) (28,068,960)
Extraordinary item - loss on early
extinguishment of debt (417,389) (615,793) -
Net income (loss) attributable to common
stock after extraordinary item ------------- ------------- -------------
$ 2,324,374 $ (1,492,380) $(28,068,960)
============= ============= =============
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 10,761,708 12,065,481 12,545,752
============= ============= =============
The accompanying notes are an integral part of these statements.
F-3
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
Deferred
Additional Retained Compensation-
Preferred Common Paid-In Earnings Restricted
Stock Stock Capital (Deficit) Stock Grants Total
------------- ------------ ------------- ------------- ------------- -------------
Balance at December 31, 1992 $ 1,500,000 $ 4,929,835 $ 34,027,121 $(17,055,545) $ (291,798) $ 23,109,613
Conversion of preferred stock (1,500,000) 428,572 1,071,428 - - -
Issuance of common stock - 540,985 2,773,048 - - 3,314,033
Restricted stock grants - (30,000) (56,095) - 135,392 49,297
Net income attributable
to common stock - - - 2,324,374 - 2,324,374
Distributions - - - (1,151,544) - (1,151,544)
------------- ------------ ------------- ------------- ------------ -------------
Balance at December 31, 1993 - 5,869,392 37,815,502 (15,882,715) (156,406) 27,645,773
------------- ------------ ------------- ------------- ------------ -------------
Issuance of preferred stock 16,000,000 - (2,000,000) - - 14,000,000
Issuance of common stock - 302,014 708,100 - - 1,010,114
Restricted stock grants - - - - 41,250 41,250
Net loss attributable
to common stock - - - (1,492,380) - (1,492,380)
------------- ------------ ------------- ------------- ------------ -------------
Balance at December 31, 1994 16,000,000 6,171,406 36,523,602 (17,375,095) (115,156) 41,204,757
------------- ------------ ------------- ------------- ------------ -------------
Issuance of preferred stock 15,000,000 - - - - 15,000,000
Issuance of common stock - 291,930 1,658,796 - - 1,950,726
Restricted stock grants - - - - 41,250 41,250
Net loss attributable
to common stock - - - (28,068,960) - (28,068,960)
------------- ------------ ------------- ------------- ------------ -------------
Balance at December 31, 1995 $ 31,000,000 $ 6,463,336 $ 38,182,398 $(45,444,055) $ (73,906) $ 30,127,773
============= ============ ============= ============= ============ =============
The accompanying notes are an intergral part of these statements.
F-4
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Year Ended December 31,
---------------------------------------------
1993 1994 1995
------------- ------------- -------------
Cash flows from operating activities:
Income (loss) before extraordinary item $ 2,914,263 $ (58,977) $(26,161,460)
Adjustments to reconcile income (loss) before
extrordinary item to net cash
provided by operating activities:
Compensation paid in common stock 49,297 154,250 154,249
Depreciation, depletion and amortization 8,333,727 7,389,847 8,613,042
Impairment of oil and gas properties - - 29,150,000
Deferred revenue (1,601,854) (561,463) 430,000
Amortization of discounts 333,860 173,750 -
Exploration 423,600 - -
Gain on sales of property (111,605) (327,760) (2,608,088)
Bad debt expense - 80,466 -
------------- ------------- -------------
Working capital provided by operations 10,341,288 6,850,113 9,577,743
Decrease (increase) in accounts receivable 3,969,148 (3,287,610) (6,272,630)
Decrease (increase) in prepaid expenses and other (73,976) 106,547 79,893
Increase in accounts payable and accrued expenses 2,251,463 3,707,373 5,022,466
------------- ------------- -------------
Net cash provided by operating activities 16,487,923 7,376,423 8,407,472
------------- ------------- -------------
Cash flows from investing activities:
Proceeds from sales of properties 690,713 396,152 3,084,603
Collections of notes receivable 792,350 166,973 -
Capital expenditures and acquisitions (18,637,371) (16,386,087) (61,809,490)
Repurchase of volumetric production payment - (8,149,276) -
Purchase of other assets (260,516) - -
------------- ------------- -------------
Net cash used for investing activities (17,414,824) (23,972,238) (58,724,887)
------------- ------------- -------------
Cash flows from financing activities:
Borrowings 33,430,701 34,880,246 58,403,139
Proceeds from preferred stock issuances - 6,000,000 15,000,000
Proceeds from common stock issuances - 214,650 25,000
Principal payments on debt (30,381,491) (21,496,782) (24,524,550)
Financing costs (805,896) -
Stock issuance costs (129,512) (332,021) (94,774)
Distributions (1,151,544) - -
Dividends on preferred stock (172,500) - -
------------- ------------- -------------
Net cash provided by financing activities 789,758 19,266,093 48,808,815
------------- ------------- -------------
Net increase (decrease) (137,143) 2,670,278 (1,508,600)
in cash and cash equivalents
Cash and cash equivalents, beginning of year 892,113 754,970 3,425,248
------------- ------------- -------------
Cash and cash equivalents, end of year $ 754,970 $ 3,425,248 $ 1,916,648
============= ============= =============
The accompanying notes are an integral part of these statements.
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 and 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. As a result of the merger,
Stanford became a wholly owned subsidiary of the Company on November 17, 1993,
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
F-6
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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.
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.
F-7
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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 $172,500, $817,610 and $1,907,500
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.
The following is a summary of all significant noncash investing and
financing activities:
For the Year Ended December 31,
1993 1994 1995
Common stock issued in payment of
preferred stock dividends $ - $ 817,610 $ 1,907,500
Common stock issued for compensation $ - $ 113,000 $ 113,000
Preferred stock issued to repurchase
volumetric production payment $ - $8,000,000 $ -
Common stock issued for acquisitions $3,142,218 $ - $ -
Common stock issued in settlement
of note payable $ 301,327 $ - $ -
The Company made cash payments for interest of $2,067,368, $2,599,788 and
$5,836,119 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 five producing gas wells
and the related oil and gas leases covering 2,048 acres in South Texas for $7.3
million in cash.
F-8
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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 in
cash.
On December 23, 1994, the Company acquired interests in twenty-three wells in
South Texas for cash of $5 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 fourteen 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 million.
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.
1994 1995
Pro Forma Pro Forma
(unaudited) (unaudited)
------------ ------------
Revenues $ 52,214,000 $ 84,349,000
Net income (loss) attributable
to common stock before
extraordinary item $ 3,480,000 $(28,345,000)
Net income (loss) attributable
to common stock after
extraordinary item $ 2,864,000 $(28,345,000)
Net loss per share before
extraordinary item $ .29 $ (2.26)
Net loss per share after
extraordinary item $ .24 $ (2.26)
(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 million and an estimated market value
of $8 million, and $10,150,000 in cash to
F-9
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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 million. This amount was
capitalized as oil and gas properties in the accompanying financial statements.
(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 -
December 31,
-----------------------------------
1994 1995
------------- -------------
Proved properties $113,269,341 $154,843,663
Accumulated depreciation,
depletion and amortization (36,426,911) (55,182,192)
------------- -------------
$ 76,842,430 $ 99,661,471
============= =============
Costs Incurred - Year Ended December 31,
--------------------------------------------
1993 1994 1995
------------ ------------ ------------
Property acquisitions:
Proved properties $18,604,103 $13,576,584 $56,093,197
Unproved properties 246,681 - -
Development costs 2,389,943 1,489,712 3,666,296
Exploration costs 423,600 - -
------------ ------------ ------------
$21,664,327 $15,066,296 $59,759,493
============ ============ ============
The following presents the results of operations of oil and gas producing
activities for the three years in the period ended December 31, 1995:
Year Ended December 31,
1993 1994 1995
------------ ------------ -------------
Oil and gas sales $21,804,502 $16,854,665 $ 22,090,894
Production costs (6,673,494) (6,098,972) (7,426,626)
Depreciation, depletion
and amortization (7,952,336) (7,148,269) (8,277,500)
Impairment of oil and gas properties - - (29,150,000)
------------ ------------ -------------
Operating income (loss) 7,178,672 3,607,424 (22,763,232)
Income tax expense - - -
------------ ------------ -------------
Results of operations
excluding general and
administrative and interest
expense) $7,178,672 $ 3,607,424 $(22,763,232)
=========== ============ =============
F-10
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
(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.
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 five 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 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:
December 31,
1994 1995
------------- -------------
Bank term note $ - $ 10,000,000
Bank credit facility 37,580,000 61,590,000
12% subordinated notes 318,750 206,251
Capital lease obligations 33,593 14,681
37,932,343 71,810,932
------------- -------------
Less current portion (7,009,864) (18,677,181)
------------- -------------
$ 30,922,479 $ 53,133,751
============= =============
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 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).
F-11
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Aggregate maturities of long-term debt for the five years ending December
31, are as follows:
1996 $18,677,181
1997 12,813,751
1998 40,320,000
1999 -
2000 -
-----------
$71,810,932
===========
(8) LEASE COMMITMENTS -
The Company rents office space under certain noncancellable leases and
leases data processing time under a noncancellable lease. Minimum future
payments under the leases are as follows:
1996 $ 269,468
1997 $ 257,904
1998 $ 236,185
1999 $ 177,139
2000 $ -
(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 $817,610.
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 $1,907,500.
Preferred Stock -
On December 31, 1993, the holder of 150,000 shares of the Company's 1992
Series Cumulative Convertible Preferred Stock, ("1992 Preferred Stock"),
converted all of the 1992 Preferred Stock into
F-12
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
857,143 shares of common stock of the Company. As a result of the
conversion, the 1992 Series designation was retired.
On January 7, 1994, the Company sold 600,000 shares of the Series 1994
Convertible Preferred Stock (the "Series 1994 Preferred") with a par value of
$10 per share in a private placement for $6 million. The Series 1994 Preferred
bears quarterly dividends at the rate of 22 1/2 cents 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 (i) in
cash or (ii) 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 one million shares of its 1994 Series B
Convertible Preferred Stock (the "1994 Series B Preferred") with a par value of
$10 per share in connection with the repurchase of certain 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 15 5/8 cents 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 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 for the 1994 Series B
Preferred.
On June 19, 1995, the Company sold 1,500,000 shares of the Series 1995
Convertible Preferred Stock (the "Series 1995 Preferred") with a par value of
$10 per share in a private placement for $15 million. The Series 1995 Preferred
bears quarterly dividends at the rate of 22 1/2 cents on each outstanding share
(9% per annum of the par value) and is payable quarterly. The Company can elect
to pay the dividends in cash or in shares of the Company's common stock. 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 (i) in cash or (ii)
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.
F-13
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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
granting of non-qualified stock options to purchase common stock of the Company
and the granting 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 528,573 shares of common stock plus
10% of any future issuances of common stock.
Non-qualified stock options awarded under the Incentive Plan are summarized
below:
Exercise Price
$2.00 $2.50 $3.00
----- ----- -----
Outstanding at December 31, 1992 625,000 - -
Granted in 1993 - 196,000 85,000
Exercised in 1993 (20,000) (16,750) -
Forfeited in 1993 (80,000) - -
Outstanding at December 31, 1993 525,000 179,250 85,000
Exercised in 1994 - (21,000) (15,000)
Forfeited in 1994 - (49,000) -
Outstanding at December 31, 1994 525,000 109,250 70,000
Granted in 1995 - - 97,500
Exercised in 1995 - (10,000) -
Outstanding at December 31, 1994 525,000 99,250 167,500
========= ========== =========
Exercisable at December 31, 1995 387,000 84,250 167,500
========= ========== =========
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:
Number
Number of Shares Exercise
of Shares Exercisable Price Expiration Date
--------- ----------- ----- ---------------
135,000 135,000 $ 5.75 June 1997
200,000 200,000 $ 2.75 March 1998
200,000 200,000 $ 3.00 March 1998
150,000 100,000 $ 2.25 March 1998
217,800 217,800 $ 5.00 October 1999
62,200 62,200 $ 5.00 November 1999
223,557 223,557 $ 5.00 December 1999
--------- ---------
1,188,557 1,138,557
F-14
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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 to the employee over a ten year period
with credit given for past service rendered to the Company.
The following is a summary of shares of restricted common stock awarded
under the Incentive Plan:
1993 1994 1995
---- ---- ----
Outstanding at beginning of year 390,000 330,000 330,000
======= ======= =======
Cancelled or expired (60,000) - -
======= ======= =======
Outstanding at end of year 330,000 330,000 330,000
======= ======= =======
Vested shares 195,000 225,000 255,000
======= ======= =======
A provision for the restricted stock grants is made ratably over the vesting
period. Compensation expense recognized for restricted stock grants was $49,297,
$41,250 and $41,250 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:
1994 1995
---- ----
Net deferred tax asset -
Property and equipment $(5,079,000) $ 2,548,000
Net operating loss carryforwards 9,250,000 10,544,000
Valuation allowance (4,171,000) (13,092,000)
------------ -------------
$ - $ -
============ =============
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 $1,151,544 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
million as of December 31, 1995, for income tax reporting purposes which expire
in varying amounts from 2001 to 2010. The
F-15
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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. For 1993, 1994 and 1995 the Company received
$87,000 in management fees in each year from the Partnership and earned
acquisition fees from the Partnership 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 the
Partnership at December 31, 1994 and 1995, respectively.
During 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 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 a 20.31% limited partner 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:
1994 1995
---- ----
Oil and Gas Producing Activities -
Realized Gains $ 726,166 $ 912,841
Realized Losses $ 8,616 $ 28,272
Gas Gathering, Processing and Marketing Activities -
Realized Gains $ 14,941 $ 895,495
Realized Losses $ 29,604 $ 372,575
F-16
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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 -
Year Instrument Quantity Price Remaining Term
- ---- ---------- -------- ----- --------------
1994 Natural Gas Price Swaps 9,087,434 MMBtu $2.00 Jan. 1995 to Nov. 1999
1995 - None - -
Gas Marketing Activities -
Year Instrument Quantity Price Remaining Term
- ---- ---------- -------- ----- --------------
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
During 1995, the Company settled open swap positions relating to the 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.
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,
gathers, processes and transports natural gas through its facilities.
F-17
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Financial information by industry segment is as follows:
1994 1995
----------- -----------
Revenues:
Oil and gas $16,854,665 $22,090,894
Gas marketing, processing
and gathering (1) 15,029,743 50,678,578
----------- -----------
$31,884,408 $72,769,472
=========== ===========
Operating Profit (Loss):
Oil and gas (2) $ 3,607,424 $(22,763,232)
Gas marketing, processing
and gathering (2) 489,607 1,440,365
----------- ------------
$ 4,097,031 $(21,322,867)
=========== ============
Identifiable Assets:
Oil and gas $76,842,430 $ 99,661,471
Gas marketing, processing
and gathering 1,004,918 2,321,631
----------- ------------
$77,847,348 $101,983,102
=========== ============
Capital Expenditures:
Oil and gas $15,066,296 $ 59,759,493
Gas marketing, processing
and gathering 1,098,465 2,008,216
----------- ------------
$16,164,761 $ 61,767,709
=========== ============
Depreciation, Depletion and Amortization:
Oil and gas $ 7,148,269 $ 8,277,500
Gas marketing, processing
and gathering 8,522 119,709
----------- -----------
$ 7,156,791 $ 8,397,209
=========== ===========
(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. 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.
(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
F-18
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
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:
1993 1994 1995
-------------------------- -------------------------- ---------------------------
Oil Gas Oil Gas Oil Gas
(Bbls) (Mcf) (Bbls) (Mcf) (Bbls) (Mcf)
---------- ----------- ----------- ---------- ----------- -----------
Proved Reserves:
Beginning of year 2,259,415 76,061,418 6,110,934 74,362,551 5,119,142 92,839,597
Revisions of previous estimates 1,775,622 (16,703,559) (1,135,171) (3,301,162) (2,843,511) (18,809,169)
Extensions and discoveries - - 19,224 4,453,439 - -
Purchases of minerals in place (1) 2,512,387 25,116,583 388,312 23,465,952 1,858,918 108,431,748
Sales of minerals in place (158,085) (2,838,374) (1,434) (84,003) - -
Production (2) (278,405) (7,273,517) (262,723) (6,057,180) (355,520) (9,296,832)
---------- ----------- ----------- ------------ ----------- ------------
End of year 6,110,934 74,362,551 5,119,142 92,839,597 3,779,029 173,165,344
---------- ----------- ----------- ----------- ----------- ------------
Proved Developed Reserves:
Beginning of year 816,113 32,194,895 1,654,902 42,908,631 1,503,919 62,827,267
========== =========== =========== ============ =========== ===========
End of year 1,654,902 42,908,631 1,503,919 62,827,267 2,562,481 130,375,273
========== =========== =========== ============ =========== ============
(1) 1994 purchases of minerals in place include the repurchase of a volumetric production payment of 10,721,629 Mcf.
(2) Excludes 1,240,305 and 456,475 Mcf of gas production delivered to a major natural gas company under a volumetric production
payment in 1993 and 1994, respectively.
Standardized Measure of Discounted Future Net Cash Flows Relating
to Proved Reserves:
December 31,
1994 1995
---- ----
Cash Flows Relating to Proved Reserves:
Future Cash Flows $ 243,811,000 $ 426,131,000
Future Costs:
Production (73,899,000) (121,727,000)
Development (25,366,000) (39,462,000)
Future Net Cash Flows Before Income Taxes 144,546,000 264,942,000
Future Income Taxes (17,028,000) (45,175,000)
Future Net Cash Flows 127,518,000 219,767,000
10% Discount Factor (49,037,000) (73,261,000)
------------- -------------
Standardized Measure of Discounted Future
Net Cash Flows $ 78,481,000 $ 146,506,000
============= =============
F-19
COMSTOCK RESOURCES, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Changes in Standardized Measure of Discounted Future Net Cash Flows
Relating to Proved Reserves:
For the Year Ended December 31,
1993 1994 1995
---- ---- ----
Standardized Measure, Beginning of Year $ 45,335,000 $ 60,757,000 $ 78,481,000
Net Change in Sales Price, Net of Production Costs (4,047,000) (3,392,000) 9,450,000
Development Costs Incurred During the Year Which
Were Previously Estimated - 347,000 822,000
Revisions of Quantity Estimates (4,062,000) (6,457,000) (30,298,000)
Accretion of Discount 4,545,000 6,095,000 7,874,000
Changes in Future Development Costs 9,545,000 2,695,000 13,248,000
Changes in Timing and Other (7,425,000) (2,883,000) (2,590,000)
Extensions and Discoveries - 3,582,000 -
Purchases of Reserves In Place 32,551,000 28,083,000 85,706,000
Sales of Reserves In Place (2,073,000) (84,000) -
Sales, Net of Production Costs (13,529,000) (10,194,000) (14,664,000)
Net Changes in Income Taxes (83,000) (68,000) (1,523,000)
------------ ------------ -------------
Standardized Measure, End of Year $ 60,757,000 $ 78,481,000 $ 146,506,000
============ ============ =============
(15) SUBSEQUENT EVENT -
During the first quarter of 1996, the Company entered into agreements to
acquire Black Stone Oil Company and the interests of additional working interest
owners in certain producing oil and gas properties as well as a substantial
interest in undeveloped oil and gas leases located in East Texas for total cash
consideration of approximately $102.9 million. Black Stone Oil Company is a
privately held company based in Houston, Texas and is the operator of and owns
interests in the oil and gas properties being acquired.The producing properties
to be acquired are located in the Double A Wells field in Polk County, Texas.
The estimated net proved oil and gas reserves attributable to the interests
being acquired are estimated at 92 billion cubic feet of natural gas and 5
million barrels of oil as of January 1, 1996, the effective date of the
acquisition. Such reserves have estimated future net cash flows of $233 million
and estimated discounted future net cash flows of $140 million (reserve
estimates are unaudited). The acquisition is expected to close by May 1, 1996
and to be financed under a $175 million credit facility being provided by the
Company's banks.
F-20
INDEX TO EXHIBITS
Exhibit
Number Exhibit Page
2.1 Agreement and Plan of Reorganization by and among the
Company, Comstock Acquisition, Inc. and Stanford Offshore
Energy, Inc. and the Shareholders of Stanford Offshore
Energy, Inc. (incorporated herein by reference to Exhibit 2
to the Company's Current Report on Form 8-K dated November
17, 1993, as amended by Form 8 dated January 14, 1994 and
Form 8-K/A dated March 29, 1994).
2.2 Purchase and Sale Agreement, dated May 16, 1995 between
Comstock Resources, Inc. and Sonat Exploration Company
(incorporated herein by reference to Exhibit 2(a) to
Company's Current Report on Form 8-K dated May 16, 1995).
3.1* Restated Articles of Incorporation of the Company. E-5
3.2 Bylaws of the Company as adopted on July 16, 1990
(incorporated herein by reference to Exhibit 3.7 to
Company's Annual Report on Form 10-K for the fiscal year
ended December 31, 1990).
4.1 Certificate of Designation, Preferences and Rights of Series
A Junior Participating Preferred Stock dated December 6,
1990 (incorporated herein by reference to Exhibit 3.6 to the
Company's Annual Report on Form 10-K for the fiscal year
ended December 31, 1990).
4.2 Certificate of Voting Powers, Designations, Preferences, and
Relative, Participating, Optional or Other Special Rights of
the Series 1994 Convertible Preferred Stock (incorporated
herein by reference to Exhibit 3(a) to the Company's Current
Report on Form 8-K dated January 7, 1994).
4.3 Certificate of Voting Powers, Designations, Preferences, and
Relative, Participating, Optional or Other Special Rights of
the 1994 Series B Convertible Preferred Stock (incorporated
herein by reference to Exhibit 3(a) to the Company's Current
Report on Form 8-K dated July 22, 1994).
4.4 Certificate of Voting Powers, Designations, Preferences, and
Relative, Participating, Optional or Other Special Rights of
the Series 1995 Convertible Preferred Stock (incorporated
herein by reference to Exhibit 3(a) to the Company's Current
Report on Form 8-K dated June 19, 1995).
E-1
Exhibit
Number Exhibit Page
4.5 Rights Agreement, dated as of December 10, 1990, by and
between the Company and Society National Bank (successor to
Ameritrust Texas N.A.), as Rights Agent, (incorporated
herein by reference to Exhibit 1 to Company's Registration
Statement on Form 8-A, dated December 14, 1990).
4.6 First Amendment to the Rights Agreement, by and between the
Company and Society National Bank (successor to Ameritrust
Texas, N.A.), as Rights Agent, dated January 7, 1994
(incorporated herein by reference to Exhibit 3.6 to the
Company's Annual Report on Form 10-K for the fiscal year
ended December 31, 1993).
4.7* Second Amendment to the Rights Agreement, by and between the E-8
Company and Bank One, Texas N.A. (successor to Society
National Bank), as Rights Agent, dated April 1, 1995. E-8
4.8* Third Amendment to the Rights Agreement, by and between the E-10
Company and Bank One, Texas N.A., as Rights Agent, dated
June 16, 1995. E-10
4.9* Fourth Amendment to the Rights Agreement, by and between the E-13
Company and American Stock Transfer and Trust Company
(successor to Bank One, Texas N.A.), as Rights Agent, dated
September 1, 1995.
10.1 Credit Agreement, dated as of July 31, 1995, between the
Company, NBD Bank, N.A., Bank One Texas N.A. and NBD Bank,
N.A., as agent (incorporated herein by reference to Exhibit
99(c) to the Company's Current Report on Form 8-K dated May
16, 1995, as amended by Form 8-K/A dated August 4, 1995).
10.2* Amendment No. 1 to the Credit Agreement effective December E-16
31, 1995, between the Company, NBD Bank, N.A., Bank One,
Texas N.A. and NBD Bank, N.A., as agent. E-16
E-2
Exhibit
Number Exhibit Page
10.3* Employment Agreement, dated July 1, 1995, by and between the E-21
Company and M. Jay Allison. E-21
10.4* Employment Agreement, dated July 1, 1995, by and between the E-27
Company and Roland O. Burns. E-27
10.5 Comstock Resources, Inc. 1991 Long-term Incentive Plan,
dated as of April 1, 1991 (incorporated herein by reference
to Exhibit 10.8 to the Company's Annual Report on Form 10-K
for the fiscal year ended December 31, 1991).
10.6 Form of Nonqualified Stock Option Agreement, dated April 2,
1991, between the Company and certain officers and directors
of the Company (incorporated herein by reference to Exhibit
10.9 to the Company's Annual Report on Form 10-K dated
December 31, 1991).
10.7 Form of Restricted Stock Agreement, dated April 2, 1991,
between the Company and certain officers of the Company
(incorporated herein by reference to Exhibit 10.10 to the
Company's Annual Report on Form 10-K dated December 31,
1991).
10.8 Stock Purchase Warrant Agreement, (W-1), dated as of May 22,
1991 by and between the Company and Liberty Life Insurance
Company (incorporated herein by reference to Exhibit 10.21
to the Company's Annual Report on Form 10-K dated December
31, 1991).
10.9 Warrant Modification Agreement, (W-1), dated April 8, 1992,
by and between the Company and Liberty Life Insurance
Company (incorporated herein by reference to Exhibit 10.18
to the Company's Annual Report on Form 10-K dated December
31, 1992).
10.10 Stock Purchase Warrant Agreement, (W-2), dated May 22, 1991,
by and between the Company and Liberty Life Insurance
Company (incorporated herein by reference to Exhibit 10.22
to the Company's Annual Report on Form 10-K dated December
31, 1991).
E-3
Exhibit
Number Exhibit Page
10.11 Warrant Modification Agreement, (W-2), dated April 8, 1992,
by and between the Company and Liberty Life Insurance
Company (incorporated herein by reference to Exhibit 10.20
to the Company's Annual Report on Form 10-K dated December
31, 1992).
10.12 Stock Purchase Warrant Agreement, (W-3), dated April 8,
1992, by and between the Company and Liberty Life Insurance
Company (incorporated herein by reference to Exhibit 10.21
to the Company's Annual Report on Form 10-K dated December
31, 1992).
10.13 Form of Stock Option Agreement, dated October 12, 1994 by
and between the Company and Christopher T. H. Pell, et al
(incorporated herein by reference to Exhibit 10.18 to the
Company's Annual Report on Form 10-K dated December 31,
1994).
10.14 Lease Agreement, dated as of December 20, 1994, by and
between the Company and Occidental Tower Corporation
(incorporated herein by reference to Exhibit 10.19 to the
Company's Annual Report on Form 10-K dated December 31,
1994).
21 * Subsidiaries of the Company. E-33
23 * Consent of Independent Public Accountants. E-35
27 * Financial Data Schedule. E-37
- --------
* Filed herewith.