UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-K
MARK ONE
|X| ANNUAL REPORT PURSUANT TO SECTION 13 or 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934 [FEE REQUIRED]
For the Fiscal Year Ended December 31, 1996
|_| TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Commission File Number 0-19931
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
(Exact name of registrant as specified in its charter)
Delaware 84-1176750
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
4582 South Ulster Street Parkway
Suite 1700
Denver, Colorado 80237
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (303) 850-7373
Securities Registered Pursuant to Section 12(b) of the Act:
Name of each exchange
Title of each class on which registered
None None
Securities Registered Pursuant to Section 12(g) of the Act:
Common Stock, $.01 par value
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 or any amendment to this
Form 10-K. |X|
The aggregate market value of the voting stock held by nonaffiliates of the
registrant as of March 20, 1997 was approximately $38,473,848.
Shares of Common Stock outstanding at March 20, 1997: 992,514 Shares.
Page 1 of 50 (Exhibit begins on Page 49)
<PAGE>
PART I
ITEM 1 - BUSINESS
Hallwood Consolidated Resources Corporation ("HCRC" or the "Company") is a
Delaware corporation engaged in the development, production and sale of oil and
gas, and in the acquisition, exploration, development and operation of oil and
gas properties. The principal objective of HCRC is to pursue asset growth
through the replacement and enhancement of oil and gas reserves.
HCRC does not engage in any other line of business nor does it have any
employees. Hallwood Petroleum, Inc. ("HPI"), an affiliate of HCRC, operates the
properties and administers the day to day activities of HCRC and its affiliates.
On March 20, 1997, HPI had 127 employees.
Marketing
The oil and gas produced from the properties owned by HCRC has typically been
marketed through normal channels for such products. Oil is generally sold to
purchasers at field prices posted by the principal purchasers of crude oil in
the areas where the producing properties are located. In response to the
volatility in the oil markets, HCRC entered into financial contracts for hedging
the price of between 5% and 44% of its estimated oil production for 1997 through
1999.
The majority of HCRC's gas production is sold on the spot market and is
transported in intrastate and interstate pipelines. HCRC has entered into
financial contracts for hedging the price of between 12% and 43% of its
estimated gas production for 1997 through 2000.
The purpose of the hedges is to provide protection against price drops and to
provide a measure of stability in the volatile environment of oil and natural
gas spot pricing. The amounts received or paid upon settlement of these
contracts are recognized as revenue at the time the hedged volumes are sold.
Both oil and natural gas are purchased by refineries, major oil companies,
public utilities, industrial customers and other users and processors of
petroleum products. HCRC is not confined to, nor dependent upon, any one
purchaser or small group of purchasers. Accordingly, the loss of a single
purchaser, or a few purchasers, would not materially affect HCRC's business
because there are numerous purchasers in the areas in which HCRC sells it
production. However, for the years ended December 31, 1996, 1995 and 1994,
purchases by the following companies exceeded 10% of the total oil and gas
revenues of the HCRC:
1996 1995 1994
------ ------ -----
Koch Oil Company 23% 27% 34%
Conoco Inc. 13% 14% 15%
Scurlock Permian Corporation 14%
El Paso Field Services 11%
Factors, if they were to occur, which might adversely affect HCRC include
decreases in oil and gas prices, the reduced availability of a market for
production, rising operating costs of producing oil and gas, compliance with and
changes in environmental control statutes and increasing costs and difficulties
of transportation.
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<PAGE>
Competition
In the course of its development and exploration activities, HCRC must compete
with other entities for the acquisition of undeveloped acreage and desirable
leaseholds. As described under "Marketing," production is sold on the spot
market, thereby reducing sales competition. Moreover, oil and gas must compete
with coal, atomic energy, hydro-electric power and other forms of energy.
Regulation
Production and sale of oil and gas are subject to federal and state governmental
regulations in a variety of ways including environmental regulations, labor
laws, interstate sales, excise taxes and federal and Indian lands royalty
payments. Failure to comply with these regulations may result in fines,
cancellation of licenses to do business and cancellation of federal, state or
Indian leases.
The production of oil and gas is subject to regulation by the state regulatory
agencies in the states in which HCRC does business. These agencies make and
enforce regulations to prevent waste of oil and gas and to protect the rights of
owners to produce oil and gas from a common reservoir. The regulatory agencies
regulate the amount of oil and gas produced by assigning allowable production
rates to wells capable of producing oil and gas.
Environmental Considerations
The exploration for, and development of, oil and gas involves the extraction,
production and transportation of materials which, under certain conditions, can
be hazardous or can cause environmental pollution problems. In light of the
current interest in environmental matters, HCRC cannot predict the effect of
possible future public or private action on its business. HCRC is continually
taking actions it believes are necessary in its operations to ensure conformity
with applicable federal, state and local environmental regulations and does not
presently anticipate that compliance with federal, state and local environmental
regulations will have a material adverse effect upon capital expenditures,
earnings or the competitive position of HCRC in the oil and gas industry.
Insurance Coverage
HCRC is subject to all the risks inherent in the exploration for, and
development of, oil and gas, including blowouts, fires and other casualties.
HCRC maintains insurance coverage as is customary for entities of a similar size
engaged in operations similar to that of HCRC, but losses can occur from
uninsurable risks or in amounts in excess of existing insurance coverage. The
occurrence of an event which is not insured or not fully insured could have an
adverse impact upon HCRC's earnings, cash flows and financial position.
ITEM 2 - PROPERTIES
Exploration and Development Projects
In 1996, HCRC incurred $9,760,000 in direct property additions and exploration
and development costs and approximately $1,740,000 for an odd lot share
repurchase discussed below. The costs were comprised of approximately $7,518,000
for domestic exploration and development expenditures and approximately
$2,182,000 for property acquisitions. In 1996, HCRC participated in
approximately 120 drilling or recompletion projects, the highlights of which are
discussed below. HCRC's 1996 capital program led to the replacement, through
acquisitions and drilling, of 126% of the equivalent barrels produced during
1996. Overall replacement, including revisions to prior year reserves, was 183%
of 1996 production. Sales of reserves in place in 1996 were approximately 15% of
1996 production.
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<PAGE>
Odd Lot Repurchase
The Company made an offer to repurchase odd lot holdings of 99 or fewer shares
from its stockholders of record as of November 30, 1995. The offer was initially
for the period from November 30, 1995 through January 5, 1996 and was
subsequently extended through January 26, 1996. The Company repurchased a total
of 98,869 shares through the January 26, 1996 closing date for $2,382,000 at a
purchase price of $24.09 per share, of which $1,312,000 was expended during
1996.
On April 1, 1996, HCRC made another offer to purchase holdings of 99 or fewer
shares from its stockholders of record as of March 25, 1996. The offer was for
the period from April 1, 1996 through May 3, 1996. The Company repurchased a
total of 25,930 shares at a purchase price of $34.00 per share. HCRC resold
12,965 of these shares to Hallwood Energy Partners, L.P. ("HEP") at the price
paid by HCRC for such shares.
Property Sales
During the first quarter of 1996, HCRC received approximately $175,000 for the
sale of its interests in the Hoople Field in Crosby County, Texas. HCRC also
received $21,000 in early April for the sale of various nonstrategic properties
at auction. In June 1996, HCRC completed the sale of its interests in the
Bethany Longstreet area of Louisiana (approximately 175,000 equivalent barrels
of oil, measured using December 31, 1995 pricing) for approximately $1,100,000.
Capital Projects
HCRC continued to devote capital resources to the West Texas Kermit area in
1996. HCRC has drilled or participated in the drilling of seventeen wells,
fifteen of which were successful, and participated in nine recompletions, six of
which were successful, for a total cost to HCRC of approximately $890,000. The
wells in this area are currently producing approximately 750 gross equivalent
barrels of oil per day. HCRC's interest in these wells averages 15%. HCRC has
plans to drill or recomplete up to fifteen additional wells in 1997. HCRC has
begun discussing secondary recovery projects with its partners.
HCRC acquired 106 square miles of three dimensional (3-D) seismic data on the
Cowden Ranch in Crane County, Texas. The prospect is operated by a major oil
company, and HCRC has a 12.5% working interest. HCRC's share of costs in 1996 is
$455,000. Seismic interpretation was completed in the third quarter. Two
exploratory wells, both of which were dry, were drilled in the fourth quarter at
a cost to HCRC of $172,000 and a third exploratory well is being drilled in
1997.
HCRC acquired 3-D seismic data and related acreage in the Merkel Project Area
which covers 18 square miles in Jones, Taylor and Nolan Counties, Texas.
Expenditures during 1996 totaled $538,000. Thus far, HCRC has participated in
drilling eight wells on four exploration prospects for a total cost to HCRC of
$200,000, including one well drilled in late 1995. Seven of the eight wells have
been successful. These wells currently are producing approximately 375 gross
barrels of oil per day. HCRC's nonoperating interest in this production is 10%.
HCRC acquired an additional 74 square miles of 3-D seismic data, which is
presently being interpreted, in the same area. HCRC's working interest in this
area averages 27.5%, and prospect exploratory drilling will begin in the first
quarter of 1997. HCRC anticipates at least 10 prospects will be tested in 1997
and in subsequent years on this portion of the project area.
HCRC incurred approximately $310,000 in the first quarter, net to HCRC's
interest, for four recompletions and one drilled well in the Rocker "b" Ranch in
Reagan County, Texas. During the first quarter, HCRC also acquired interests in
five additional producing leases on the Rocker "b" Ranch for a total of $93,000.
Effective April 1, 1996, HCRC repaid its share of the bank debt of Hallwood
Spraberry Drilling Company, L.L.C. ("HSD") through additional borrowings under
its bank credit agreement and assumed direct ownership of its share of HSD's
properties. In the second and third quarters of 1996, HCRC recompleted seven
wells, three of which were successful, and drilled one additional well for a
total cost to HCRC of $275,000. Current production from all Rocker "b" 1996
capital projects
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<PAGE>
averages 185 gross equivalent barrels of oil per day. HCRC's share of this
production is approximately 32%. Minimal additional drilling or workovers are
expected in the area in 1997. HCRC drilled or worked over a total of 95 wells in
this area over the past three years.
HCRC participated in the drilling of two nonoperated wells in Williams County,
North Dakota in the latter part of 1995 and the first quarter of 1996, one of
which was dry and the other only marginally successful, for a total cost to HCRC
of approximately $310,000. HCRC also drilled an exploratory dry hole in Richland
County, Montana, at a cost of $150,000. HCRC completed an Interlake Formation
development well, drilled in the third quarter at a net cost of approximately
$600,000. This well is currently producing at a rate of 80 barrels of oil per
day, and HCRC's interest is 45%.
In the San Juan Basin area, HCRC acquired interests in four wells in Rio Arriba
County, New Mexico, and through an affiliate, LaPlata Associates LLC ("LPA"),
acquired interests in 34 coal bed methane wells located in LaPlata County,
Colorado for $1,450,000. HCRC's interest in the wells added 9.5 bcf of gas to
its reserve base, which represented approximately 94% of its estimated 1996
production. The acquisition was completed on July 1, 1996. Nine
refracs/recompletions have been completed since July 1 at a net cost to HCRC of
approximately $720,000. Numerous other recompletions and facility projects were
completed in 1996, at an estimated total net cost to HCRC of $280,000. Gross
production has increased by approximately 4,000 mcf of gas per day as a result
of the work done to date. Similar activity levels in 1997 are anticipated on
these newly acquired properties. In other parts of the New Mexico portion of the
San Juan Basin area, HCRC has recompleted three wells, two of which were
successful, drilled two wells and is converting another well to be a disposal
well. The total cost for this work was $545,000, and HCRC's share of this
production is approximately 41%.
HCRC participated in a 13 square mile 3-D seismic shoot at the Packsaddle
Project in the Big Horn Basin of Wyoming. The data is now being processed and
additional development and exploration is expected in the area following HCRC's
previous discovery. HCRC's ownership in the Big Horn Basin continues to increase
through a joint venture created to evaluate a 4,000 mile 2-D Seismic Data Base
from which HCRC hopes to create additional drillable prospects.
HCRC also incurred approximately $150,000 in 1996 for the successful drilling of
a 10,000 foot exploratory well in a structural 3-D seismic play in Glasscock
County, Texas. Production from this well is currently averaging 250 gross
equivalent barrels of oil per day. HCRC's interest in this well is 13%.
Additional nonproducing reserves from another zone were recorded at year end as
well. As of year end, HCRC has committed to at least one more exploratory well
in 1997.
Numerous other projects, which are individually less significant, have been
completed or are underway in Kansas, Louisiana, Texas and New Mexico including
participation in five other 3-D seismic data acquisition programs not included
in the above activity.
1997 Plans
For 1997, HCRC's capital budget, which will be paid from cash generated from
operations and cash on hand, has been set at $12,500,000. In addition to the
above mentioned plans, HCRC's domestic exploration plans also include projects
in Texas, Wyoming, Montana, Colorado, New Mexico and others. HCRC will consider
acquisitions in strategic areas utilizing its capital budget supplemented by
external financing. HCRC will continue to consider international projects in
1997 on a selective basis.
HCRC will aggressively pursue exploitation and development of existing
opportunities in Texas, Wyoming, Colorado, Kansas, New Mexico and Utah.
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<PAGE>
Company Reserves, Production and Discussion by Significant Areas and Fields
The following table presents the December 31, 1996 reserve data by significant
areas and fields.
<TABLE>
<CAPTION>
Present Value of
Proved Reserve Quantities Estimated Future Net Cash Flows
Proved Proved
Mcf of Gas Bbls of Oil Undeveloped Developed Total
(In thousands)
<S> <C> <C> <C> <C> <C>
Kansas 1,123 2,837 $2,275 $ 15,072 $ 17,347
Scott/West Ridge 10,001 210 30,739 30,739
Southeastern New Mexico 4,253 281 9,525 9,525
San Juan Basin 31,083 33,770 33,770
West Texas 9,845 2,977 4,863 30,896 35,759
Other 8,596 876 944 5,916 6,860
------ ----- ------ -------- --------
64,901 7,181 $8,082 $125,918 $134,000
====== ===== ===== ======= =======
</TABLE>
The following table presents the oil and gas production for significant areas
and fields.
<TABLE>
<CAPTION>
Production for the Production for the
Year Ended 1996 Year Ended 1995
----------------- ----------------
Mcf of Gas Bbls of Oil Mcf of Gas Bbls of Oil
---------- ----------- ---------- -----------
(In thousands)
<S> <C> <C> <C> <C>
Kansas 104 220 160 280
Scott/West Ridge 1,697 34 1,817 40
Southeastern New Mexico 779 44 869 52
San Juan Basin 3,374 3,234
West Texas 923 326 526 218
Other 1,403 213 465 129
------ ---- ------ ----
8,280 837 7,071 719
====== ==== ====== ====
</TABLE>
The following table presents the Company's extensions and discoveries by
significant areas and fields.
<TABLE>
<CAPTION>
For the Year Ended 1996 For the Year Ended 1995
Mcf of Gas Bbls of Oil Mcf of Gas Bbls of Oil
(In thousands)
<S> <C> <C> <C> <C>
Kansas 237 122
Southeastern New Mexico 24 37 511 115
San Juan Basin 792 1,112
West Texas 593 367 5,049 1,942
Other 301 87 876 582
------- ----- ------ ------
1,947 491 7,548 2,761
====== ==== ====== ======
</TABLE>
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Kansas
The Kansas area consists of 223 producing wells, of which 213 are operated by
HPI and 10 are operated by unaffiliated entities. The wells are located in 15
counties primarily in the Central Kansas Uplift and produce principally from the
Arbuckle and numerous Lansing-Kansas City formation zones from 3,000 feet to
6,500 feet. During 1996, HCRC drilled one successful development well, and
performed 15 recompletions, nine of which were successful. The Kansas area is a
mature operation where recompletions and limited development drilling represent
the most prudent plans for future asset base protection. HCRC plans to sell
three properties in this area in 1997 and will continue to evaluate and divest
nonstrategic properties.
Scott/West Ridge
The Scott/West Ridge area consists area consists of 10 active gas wells, one
shut-in gas well and six salt water disposal wells located in Lafayette Parish,
Louisiana. The wells produce principally from the Bol Mex formations at 13,500
to 14,500 feet and are operated by HPI. The four most significant wells in the
area, all of which were drilled by HPI since 1989, are the A. L. Boudreaux #1,
the G. S. Boudreaux Estate #1, the Lessin Fontenot #1 and the Evangeline Shrine
Club #1. During 1996, HCRC performed one workover in this area which was
successful, and participated in one unsuccessful exploration well operated by
another party.
Southeastern New Mexico
The Southeastern New Mexico area consists of 60 producing wells, 38 of which are
operated by HPI, which produce primarily gas and are located on the northwestern
edge of the Delaware Basin in Lea, Eddy and Chaves Counties, New Mexico. These
wells produce at depths ranging from approximately 2,500 feet to 14,000 feet
from the Delaware, Atoka, Bone Springs and Morrow formations. During 1996, HCRC
participated as a nonoperator in two successful development wells and as an
operator, performed four recompletions, three of which were successful.
During 1997, HCRC plans to perform several additional recompletions.
San Juan Basin
The San Juan Basin region consists of wells located in San Juan County, New
Mexico and LaPlata County, Colorado. In 1996, HCRC and HEP acquired interests in
38 wells from a subsidiary of Public Service Company of Colorado. The wells are
located primarily in LaPlata County, Colorado and produce from the Fruitland
Coal formation at approximately 3,200 feet. An unaffiliated large East Coast
financial institution formed an entity to effectively utilize the Section 29 tax
credits generated by the wells. The project was financed through a third party
lender with a production payment structure. Since the acquisition, HCRC has
recompleted 10 of the newly acquired wells, seven successfully. Several
additional recompletions will be done in 1997.
In San Juan County, New Mexico, HPI operates 54 wells, 34 of which produce from
the Fruitland Coal formation at approximately 2,200 feet and 20 of which produce
from the Pictured Cliffs, Mesa Verde and Dakota formations at 1,200 to 7,000
feet. During 1996, HPI successfully drilled two additional coal bed methane
wells, recompleted a well for use as a salt water disposal well in the Entrada
formation and recompleted two Fruitland Coal wells, one successfully. HPI's
acreage position has been fully drilled. Several recompletions are planned for
1997.
West Texas
The West Texas area is comprised of three significant groups of properties. The
West Texas Spraberry area consists of 363 producing wells, nine salt water
disposal wells and 24 shut-in wells in Dawson, Upton, Reagan and Irion Counties.
HPI operates 387 of these wells. Most of the current production from the wells
is from the Upper and Lower Spraberry, Clearfork, Canyon, Dean and Fusselman at
depths ranging from 5,000 feet to 9,000 feet. During 1996, HCRC sold its
interest in 35 operated and 31 outside operated properties in this area. Adding
to the field discovered in 1995, HCRC successfully drilled two wells and
recompleted 23 wells in eastern Reagan County, 19 of which were successful. HCRC
plans several recompletions in this area in 1997.
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<PAGE>
The West Texas Kermit/Keystone area consists of 48 producing wells, 33 of which
are operated by HPI. The primary focus of this area is the development of the
Holt and San Andres formations at a depth of 5,100 feet on several leases in
Winkler County. During 1996, HCRC drilled 15 wells, 12 of which were successful.
During 1997, up to 16 wells may be drilled. A study is underway for a secondary
recovery project.
The West Texas Merkel/SW Lana area consists of seven producing wells in Jones,
Nolan and Taylor Counties, Texas. All of these wells are outside operated. The
primary focus of the area is exploitation of the Canyon, Strawn and Ellenburger
formations. HCRC conducted a 3-D seismic project during 1996 and, during 1997,
will drill locations identified by the seismic project.
Average Sales Prices and Production Costs
The following table presents the average oil and gas sales price and average
production costs per equivalent barrel computed at the ratio of six mcf of gas
to one barrel of oil.
<TABLE>
<CAPTION>
1996 1995 1994
------ ------ -----
Average sales prices (including effects of hedging):
<S> <C> <C> <C>
Oil and condensate (per bbl) $20.13 $17.10 $15.72
Natural gas (per mcf) 1.99 1.62 1.81
Production costs (per equivalent bbl) 4.68 4.49 5.45
</TABLE>
Productive Oil and Gas Wells
The following table summarizes the productive oil and gas wells as of December
31, 1996 attributable to HCRC's direct interests. Productive wells are producing
wells and wells capable of production. Gross wells are the total number of wells
in which HCRC has an interest. Net wells are the sum of HCRC's fractional
interests owned in the gross wells.
Gross Net
Productive Wells
Oil 636 246
Gas 302 102
--- ---
938 348
=== ===
Oil and Gas Acreage
The following table sets forth the developed and undeveloped leasehold acreage
held directly by HCRC as of December 31, 1996. Developed acres are acres which
are spaced or assignable to productive wells. Undeveloped acres are acres on
which wells have not been drilled or completed to a point that would permit the
production of commercial quantities of oil and gas, regardless of whether or not
such acreage contains proved reserves. Gross acres are the total number of acres
in which HCRC has a working interest. Net acres are the sum of HCRC's fractional
interests owned in the gross acres.
Gross Net
Developed acreage 167,915 61,536
Undeveloped acreage 93,422 15,452
------- ------
Total 261,337 76,988
======= ======
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<PAGE>
States in which HCRC holds undeveloped acreage include Texas, Louisiana,
Montana, Wyoming, New Mexico, Kansas, Colorado, North Dakota and Michigan.
Drilling Activity
The following table sets forth the number of wells attributable to HCRC's direct
interest drilled in the most recent three years.
<TABLE>
<CAPTION>
Year Ended December 31,
1996 1995 1994
------ ------ -----
Gross Net Gross Net Gross Net
Development Wells:
<S> <C> <C> <C> <C> <C> <C>
Productive 29 6.2 66 14.4 24 6.5
Dry 4 1.0 2 .5 4 1.3
-- --- --- ---- --- ----
Total 33 7.2 68 14.9 28 7.8
== === == ==== === ====
Exploratory Wells:
Productive 1 .1 6 .6 2 .1
Dry 4 .6 5 .9 6 1.3
-- --- -- --- -- ----
Total 5 .7 11 1.5 8 1.4
== === == === === ====
</TABLE>
Office Space
HCRC is guarantor of 40% of the obligation under the Denver, Colorado office
lease which is in the name of HPI. HEP is guarantor of the remaining 60% of the
obligation. HPI leases 41,000 square feet for approximately $600,000 per year.
ITEM 3 - LEGAL PROCEEDINGS
See Note 14 to the financial statements included in Item 8 - Financial
Statements and Supplementary Data.
ITEM 4 - SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
PART II
ITEM 5 - MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER
MATTERS
HCRC's common stock has traded over the counter on the NASDAQ National Market
System under the symbol "HCRC," since June 4, 1992. As of March 20, 1997, there
were 2,639 holders of record of HCRC's common stock. The following table sets
forth, for the periods indicated, the high and low closing bid quotations for
the common stock as reported by the National Quotation Bureau. HCRC did not pay
a dividend during the periods shown. During the fourth quarter of 1995, the
stockholders of HCRC approved a one-for-ten reverse split of HCRC's common
stock. The stockholders also approved a reduction in the number of authorized
shares of common stock to 2,000,000 and a reduction in the number of authorized
shares of preferred stock to 500,000. Both the reverse split and the reduction
in the number of shares were effective November 9, 1995.
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<PAGE>
HCRC Common Stock High Low
- ----------------- ---- ---
First quarter 1995 21 1/4 20
Second quarter 1995 23 3/4 17 1/2
Third quarter 1995 21 1/4 16 1/4
Fourth quarter 1995 26 1/2 17 1/2
First quarter 1996 37 1/8 23 1/4
Second quarter 1996 61 32
Third quarter 1996 58 45 1/4
Fourth quarter 1996 80 49
All 1995 share and per share information has been retroactively restated for the
one for ten reverse stock split effective November 9, 1995.
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<PAGE>
ITEM 6 - SELECTED FINANCIAL DATA (In thousands except per share)
The following table sets forth selected financial data regarding HCRC's
financial position and results of operations as of the dates indicated. All per
share information has been restated to reflect the one-for-ten reverse stock
split, which was effective November 9, 1995.
<TABLE>
<CAPTION>
Hallwood Consolidated Resources Corporation
As of and for the Years Ended December 31,
-------------------------------------------
1996 1995 1994 1993 1992
------ ------ ------ ------ -----
Summary of Operations
<S> <C> <C> <C> <C> <C>
Oil and gas revenues and
pipeline operations $34,308 $25,349 $20,459 $19,792 $24,359
Total revenue 34,445 25,484 20,644 21,007 24,599
Production operating expense 10,383 8,514 8,367 7,750 7,798
Depreciation, depletion and
amortization 9,246 8,206 7,340 6,414 7,042
Impairment 9,277 4,721
General and administrative
expense 4,011 4,630 3,842 3,935 4,036
Income (loss) before cumulative
effect of change in
accounting principle 8,210 (4,670) (2,974) 972 2,090
Net income (loss) 8,210 (4,670) (2,974) 809 2,090
Income (loss) per share before
cumulative effect of change
in accounting principle 8.88 (4.43) (2.78) .91 1.96
Net income (loss) per share 8.88 (4.43) (2.78) .76 1.96
Dividends per share 7.20 7.20
Balance Sheet
Working capital (deficit) $ (47) $(7,202) $ 430 $ 5,973 $ 5,671
Property, plant and
equipment, net 67,285 65,433 55,011 57,993 58,153
Total assets 78,468 73,939 62,125 70,986 74,326
Noncurrent liabilities 24,558 21,790 11,890 17,430 10,329
Stockholders' equity 43,061 36,635 43,589 46,596 53,583
</TABLE>
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<PAGE>
ITEM 7 - MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
Liquidity and Capital Resources
Cash Flow
HCRC generated $6,917,000 of cash flow from operating activities during 1996.
The other primary cash inflows were:
o $10,000,000 from borrowings under long-term debt;
o $1,368,000 from oil and gas property sales;
o $1,144,000 from distributions received from affiliates.
Cash was primarily used for:
o $9,760,000 for property additions, exploration and development costs and
investment in affiliate;
o $6,338,000 for refinance of Spraberry investment;
o $1,750,000 for stock repurchases;
o $2,000,000 for payments of long-term debt;
o $118,000 for payments on contract settlement obligation.
When combined with miscellaneous other cash activity during the year, the result
was a decrease in HCRC's cash of $511,000 for the year, from $1,139,000 at
December 31, 1995 to $628,000 at December 31, 1996.
Property Purchases and Capital Budget
In 1996, HCRC incurred $9,760,000 in direct property additions and exploration
and development costs, and approximately $1,750,000 for an odd lot share
repurchase. The costs were comprised of approximately $7,578,000 for domestic
exploration and development expenditures, and approximately $2,182,000 for
property acquisitions. HCRC's 1996 capital program led to the replacement,
through acquisitions and drilling, of 126% of the equivalent barrels produced
during 1996, and overall replaced 183% of its 1996 production, including
revisions to prior year reserves.
HCRC's significant direct exploration and development expenditures in 1996
included approximately $890,000 for the drilling of seventeen wells, fifteen of
which were successful, and participation in nine recompletions, six of which
were successful, in the West Texas Kermit area; approximately $455,000 for 3-D
seismic data and $172,000 for two exploratory wells, both of which were dry, in
Crane County, Texas; approximately $538,000 for 3-D seismic data and related
acreage and $200,000 for the drilling of eight wells, seven of which were
successful, in the Merkel Project area in Texas; approximately $310,000 for the
drilling of two nonoperated wells, one of which was successful, in North Dakota;
approximately $150,000 for an exploratory dry hole and approximately $600,000
for an Interlake Formation development well; and approximately $585,000 for 11
recompletions and two drilled wells in Reagan County, Texas.
-12-
<PAGE>
In the San Juan Basin area of Colorado and New Mexico, HCRC, directly and
through an affiliate, acquired interests in 38 coal bed methane wells for
$1,450,000. Nine recompletions have been performed in this area for a cost of
approximately $700,000, and numerous other facility projects were completed for
approximately $280,000. HCRC spent approximately $545,000 for the recompletion
of three wells and the drilling of two wells in New Mexico.
For 1997, HCRC's capital budget, which will be paid from cash generated from
operations and cash on hand, has been set at $12,500,000. HCRC's domestic
exploitation plans include projects in Texas, Wyoming, Louisiana, Oklahoma,
Colorado and New Mexico. HCRC will continue to consider international projects
in 1997, utilizing stringent screening criteria.
During 1996, HCRC adopted Statement of Financial Accounting Standards No. 121
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to
be Disposed Of" ("SFAS 121"). SFAS 121 provides the standards for accounting for
the impairment of various long-lived assets. Substantially all of HCRC's
long-lived assets consist of oil and gas properties, which are accounted for
using the full cost method of accounting, which requires an impairment to be
recorded when total capitalized costs exceed the present value, discounted at
10%, of estimated future net revenues from proved oil and gas reserves.
Therefore, the adoption of SFAS 121 did not have a material effect on the
financial position or results of operations of HCRC.
See Item 2 - Properties, for further discussion.
The Company made an offer to repurchase odd lot holdings of 99 or fewer shares
from its stockholders of record as of November 30, 1995. The offer was initially
for the period from November 30, 1995 through January 5, 1996 and was
subsequently extended through January 26, 1996. The Company repurchased a total
of 98,869 shares through the January 26, 1996 closing date for $2,382,000 at a
purchase price of $24.09 per share, of which $1,312,000 was expended during
1996.
On April 1, 1996, HCRC made another offer to purchase holdings of 99 or fewer
shares from its stockholders of record as of March 25, 1996. The offer was for
the period from April 1, 1996 through May 3, 1996. The Company repurchased a
total of 25,930 shares at a purchase price of $34.00 per share. HCRC resold
12,965 of these shares to HEP at the price paid by HCRC for such shares,
resulting in a net repurchase to HCRC of $438,000.
Financing
During the first quarter of 1995, the Company and its banks amended their credit
agreement to extend the term date of the line of credit to May 31, 1997. The
borrowing base is currently $23,000,000, however, the Company's borrowings are
presently limited to the bank's commitment level of $22,000,000. As of December
31, 1996, the Company has borrowed $20,000,000 against the credit line. HCRC's
borrowing base is also reduced by outstanding contract settlement debt of
$948,000; therefore, its unused borrowing base totaled $2,052,000 at March 20,
1997.
Borrowings against the credit line bear interest, at the option of the Company,
at either (i) the banks' Certificate of Deposit rate plus 1.875%, (ii) the
Euro-Dollar rate plus 1.75% or (iii) the higher of the prime rate of Morgan
Guaranty Trust or the sum of one-half of 1% plus the Federal funds rate, plus
.75%. At December 31, 1996 the applicable interest rate was 7.7%. Interest is
payable at least quarterly, and quarterly principal payments of $1,250,000,
commence May 31, 1997. HCRC intends to extend the maturity date of its credit
line prior to the commencement of the amortization period. The credit facility
is secured by a first lien on approximately 80% in value of the Company's oil
and gas properties.
-13-
<PAGE>
HCRC has entered into contracts to hedge its interest rate payments on
$7,000,000 of its debt for 1996, $10,000,000 for each of 1997 and 1998 and
$5,000,000 for each of 1999 and 2000. HCRC does not use the hedges for trading
purposes, but rather for the purpose of providing a measure of predictability
for a portion of HCRC's interest payments under its debt agreement, which has a
floating interest rate. In general, it is HCRC's goal to hedge 50% of the
principal amount of its debt for the next two years and 25% for each year of the
remaining term of the debt. HCRC has entered into four hedges, of which one is
an interest rate collar pursuant to which it pays a floor rate of 7.55% and a
ceiling rate of 9.85%, and the others are interest rate swaps with fixed rates
ranging from 5.75% to 6.57%. The amounts received or paid upon settlement of
these transactions are recognized as interest expense at the time the interest
payments are due.
Stock Option Plan
During 1995, the Company adopted a stock option plan covering 53,000 shares of
Common Stock and granted options for all of the shares under the plan. The
options were granted effective July 1, 1995 at an exercise price of $20.00 per
share, which was equal to the fair market value of the Common Stock on the day
preceding the date of grant. The options expire on July 1, 2005, unless sooner
terminated pursuant to the provisions of the plan. The options are exercisable
one-third on July 1, 1995, an additional one-third on July 1, 1996, and the
remaining one-third on July 1, 1997. In addition, the plan provides that vesting
of the options may be accelerated under certain conditions.
During December 1996, options to purchase 500 shares were exercised.
During 1996, HCRC adopted the disclosure provision of Statement of Financial
Accounting Standards No. 123, "Accounting for Stock Based Compensation" ("SFAS
123"). SFAS 123 requires entities to use the fair value method to either account
for, or disclose, stock based compensation in their financial statements.
Because the Company has elected the disclosure provisions of SFAS 123, the
adoption of SFAS 123 did not have a material effect on the financial position or
results of operations of Company.
Gas Balancing
HCRC uses the sales method to account for gas balancing. Under this method, HCRC
recognizes revenue on all of its sales of production, and any over production or
under production is recovered at a future date.
As of December 31, 1996, HCRC had a net over-produced position of 462,000 mcf
($919,000 valued at average annual prices). The management of HCRC believes that
all future imbalances can be made up with production from existing wells or from
wells which will be drilled as offsets to current producing wells and that this
imbalance will not have a material effect on HCRC's results of operations,
liquidity and capital resources. The reserves discussed in Item 2 and Item 8
have been reduced by 462,000 mcf in order to reflect HCRC's gas balancing
position.
Cautionary Statement Regarding Forward-Looking Statements
In the interest of providing the Company's stockholders and potential investors
with certain information regarding the Company's future plans and operations,
certain statements set forth in this Form 10-K relate to management's future
plans and objectives. Such statements are "forward-looking statements" within
the meaning of Section 27A of the Securities Act of 1933, as amended, and
Section 21E of the Securities Exchange act of 1934, as amended. Although any
forward-looking statements contained in this Form 10-K or otherwise expressed by
or on behalf of the Company are, to the knowledge and in the judgment of the
officers and directors of the Company, expected to prove true and to come to
pass, management is not able to predict the future with absolute certainty.
Forward-looking statements involve known and unknown risks and uncertainties
which may cause the Company's actual performance and financial results in future
periods to differ materially from any projection, estimate or forecasted result.
These risks and uncertainties include, among other things, volatility of oil and
gas prices, competition, risks inherent in the Company's oil and gas operations,
the inexact nature of interpretation of seismic and other geological and
geophysical data, imprecision of
-14-
<PAGE>
reserve estimates, the Company's ability to replace and expand oil and gas
reserves, and such other risks and uncertainties described from time to time in
the Company's periodic reports and filings with the Securities and Exchange
Commission. Accordingly, stockholders and potential investors are cautioned that
certain events or circumstances could cause actual results to differ materially
from those projected.
Inflation and Changing Prices
Prices obtained for oil and gas production depend upon numerous factors that are
beyond the control of HCRC, including the extent of domestic and foreign
production, imports of foreign oil, market demand, domestic and world-wide
economic and political conditions, and government regulations and tax laws.
Prices for both oil and gas have fluctuated significantly from 1994 through
1996. The following table sets forth the average price received by HCRC for each
of the last three years and the effects of the hedging transactions described
below:
<TABLE>
<CAPTION>
Oil Oil Gas Gas
(excluding the effects (including the effects (excluding the effects (including the effects
of hedging of hedging of hedging of hedging
transactions) transactions) transactions) transactions)
(Bbl) (Bbl) (Mcf) (Mcf)
<C> <C> <C> <C> <C>
1996 $20.96 $20.13 $2.11 $1.99
1995 16.71 17.10 1.42 1.62
1994 14.68 15.72 1.76 1.81
</TABLE>
The Company has entered into numerous financial contracts to hedge the price of
its oil and natural gas. The purpose of the hedges is to provide protection
against price drops and to provide a measure of stability in the volatile
environment of oil and natural gas spot pricing.
The following table provides a summary of the Company's financial contracts:
Oil
Percent of Direct Contract
Period Production Hedged Floor Price
(per bbl)
1997 44% $17.88
1998 16% 15.07
1999 5% 15.88
Between 16% and 100% of the oil volumes hedged in each year are subject to a
participating hedge whereby HCRC will receive the contract price if the posted
futures price is lower than the contract price, and will receive the contract
price plus between 25% and 75% of the difference between the contract price and
the posted futures price if the posted futures price is greater than the
contract price. Between 35% and 100% of the volumes hedged in each year are
subject to a collar agreement whereby HCRC will receive the contract price if
the spot price is lower than the contract price, the cap price if the spot price
is higher than the cap price, and the spot price if that price is between the
contract price and the cap price. The cap prices range from $17.50 to $19.35 per
barrel.
-15-
<PAGE>
Gas
Percent of Direct
Production Contract
Period Hedged Floor Price
(per mcf)
1997 43% $1.89
1998 40% 1.91
1999 24% 1.67
2000 12% 1.86
Between 0% and 37% of the gas volumes hedged in each year are subject to a
collar agreement whereby HCRC will receive the contract price if the spot price
is lower than the contract price, the cap price if the spot price is higher than
the cap price, and the spot price if that price is between the contract price
and the cap price. The cap prices ranges from $2.78 to $2.93 per mcf.
During the first quarter through February 26, 1997, the oil price (for barrels
not hedged) averaged between $20.00 and $25.00 per barrel, and the average price
of natural gas (for mcfs not hedged) was between $1.00 and $4.40 per mcf.
Inflation
Inflation did not have a material impact on the Company in 1996 and is not
anticipated to have a material impact in 1997.
Results of Operations
The following tables are presented to contrast HCRC's revenue, expense and
earnings for discussion purposes. Significant fluctuations are discussed in the
accompanying narrative.
The "direct owned" column represents HCRC's direct royalty and working share
interests in oil and gas properties. The "HEP" column represents HCRC's share of
the results of operations of HEP. HCRC owned approximately 9% of the outstanding
limited partner units of HEP during 1994 and through the third quarter of 1995,
when HCRC's ownership increased to approximately 19%.
-16-
<PAGE>
<TABLE>
<CAPTION>
TABLE OF HCRC EARNINGS FOR MANAGEMENT DISCUSSION
(In thousands except price)
For the Year Ended December 31, 1996 For the Year Ended December 31, 1995
------------------------------------ ------------------------------------
Direct Direct
Owned HEP Total Owned HEP Total
<S> <C> <C> <C> <C> <C> <C>
Oil production (bbl) 668 169 837 611 108 719
Gas production (mcf) 6,134 2,146 8,280 5,725 1,346 7,071
Average oil price $20.17 $19.98 $20.13 $17.14 $16.84 $17.10
Average gas price $ 1.93 $ 2.15 $ 1.99 $ 1.57 $ 1.87 $ 1.62
Oil revenue $13,476 $ 3,376 $16,852 $10,475 $ 1,819 $12,294
Gas revenue 11,826 4,620 16,446 8,972 2,517 11,489
Pipeline, facilities and other revenue 510 500 1,010 1,299 267 1,566
Interest income 28 109 137 100 35 135
-------- ------ ------- ------ ----- ------
Total revenue 25,840 8,605 34,445 20,846 4,638 25,484
Production operating expense 8,203 2,180 10,383 7,191 1,323 8,514
General and administrative expense 3,186 825 4,011 3,975 655 4,630
Interest expense 1,800 730 2,530 1,316 482 1,798
Depreciation, depletion, and amortization 7,050 2,196 9,246 6,767 1,439 8,206
Impairment of oil and gas properties 8,943 334 9,277
Other 24 90 114 168 78 246
-------- ------ ------- ------- ------ --------
20,263 6,021 26,284 28,360 4,311 32,671
INCOME (LOSS) BEFORE INCOME TAXES 5,577 2,584 8,161 (7,514) 327 (7,187)
------- ----- ------ ------- ------ ------
PROVISION (BENEFIT) FOR INCOME
TAXES:
Current 301 71
Deferred (350) (2,588)
------- -------
49 (2,517)
-------- -------
NET INCOME (LOSS) $ 5,577 $ 2,584 $ 8,210 $(7,514) $ 327 $ (4,670)
====== ====== ====== ====== ====== =======
</TABLE>
-17-
<PAGE>
<TABLE>
<CAPTION>
TABLE OF HCRC EARNINGS FOR MANAGEMENT DISCUSSION
(In thousands except price)
For the Year Ended December 31, 1994
Direct
Owned HEP Total
<S> <C> <C> <C>
Oil production (bbl) 485 73 558
Gas production (mcf) 4,862 1,003 5,865
Average oil price $15.64 $16.29 $15.72
Average gas price $ 1.77 $ 2.00 $ 1.81
Oil revenue $ 7,584 $ 1,189 $ 8,773
Gas revenue 8,623 2,006 10,629
Pipeline, facilities and other revenue 849 208 1,057
Interest income 147 38 185
-------- -------- --------
Total revenue 17,203 3,441 20,644
Production operating expense 7,303 1,064 8,367
General and administrative expense 3,371 471 3,842
Interest expense 510 330 840
Depreciation, depletion, and amortization 6,192 1,148 7,340
Impairment of oil and gas properties 4,601 120 4,721
Other (18) 396 378
--------- -------- --------
21,959 3,529 25,488
LOSS BEFORE INCOME TAXES (4,756) (88) (4,844)
------- --------- -------
PROVISION (BENEFIT) FOR INCOME
TAXES:
Current 238
Deferred (2,108)
(1,870)
NET LOSS $ (4,756) $ (88) $ (2,974)
======= ======== =======
</TABLE>
<PAGE>
1996 Compared to 1995
Oil Revenue
Oil revenue increased $4,558,000 during 1996 as compared with 1995. The increase
in revenue is comprised of an 18% increase in price from $17.10 per barrel in
1995 to $20.13 per barrel in 1996, combined with a 16% increase in oil
production from 719,000 barrels in 1995 to 837,000 barrels in 1996. The increase
in production is due to increased production from developmental drilling
projects in West Texas, Montana and Wyoming, partially offset by normal
production declines.
The effect of HCRC's hedging transactions described under "Inflation and
Changing Prices" was to decrease HCRC's average oil price from $20.96 per barrel
to $20.13 per barrel, resulting in a $695,000 decrease in revenue.
Gas Revenue
Gas revenue increased $4,957,000 during 1996 as compared with 1995. The increase
is comprised of a 23% increase in the average gas price from $1.62 per mcf in
1995 to $1.99 per mcf in 1996, combined with a 17% increase in production, from
7,071,000 mcf in 1995 to 8,280,000 mcf in 1996. The increase in production is
due to increased production from developmental drilling projects in West Texas,
Montana and Wyoming, partially offset by normal production declines.
The effect of HCRC's hedging activity was to decrease HCRC's average gas price
from $2.11 per mcf to $1.99 per mcf, resulting in a $994,000 decrease in
revenue.
Pipeline and Other
Pipeline and other revenue consists of revenue derived from salt water disposal,
incentive and tax credit payments from certain coal and methane wells, and other
miscellaneous revenue. Pipeline and other revenue decreased by $556,000 during
1996 as compared with 1995, primarily due to a payout adjustment on one of
HCRC's wells which occurred during 1995.
Production Operating Expense
Production operating expense increased $1,869,000 during 1996 as compared to
1995. The increase was the result of higher taxes due to higher production, as
well as increased operating expenses in the West Texas area.
General and Administrative Expense
General and administrative expense includes costs incurred for direct
administrative services such as legal, audit and reserve reports as well as
allocated internal overhead incurred by HPI on behalf of the Company. These
costs decreased by $619,000 during 1996 as compared to 1995, primarily as a
result of decreased performance based compensation and a decrease in salaries
expense and employee benefits expense due to personnel reductions during 1995.
Interest Expense
Interest expense represents interest expense on the Company's outstanding debt,
interest incurred on the contract settlement liability related to a recoupable
take-or-pay settlement received in the third quarter of 1989, and the Company's
pro rata share of HEP's interest expense. The Company does not pay any of HEP's
interest expense. Interest expense increased $732,000 in 1996 as compared to
1995, primarily as a result of increased borrowings against the Company's credit
line.
-19-
<PAGE>
Depreciation, Depletion and Amortization Expense
Depreciation, depletion and amortization expense associated with proved oil and
gas properties increased $1,040,000 during 1996 as compared with 1995. This
increase is primarily due to a higher depletion rate due to the increased
production discussed above as well as higher capitalized costs during 1996 as a
result of capital expenditures incurred during the year.
Other
Other expense for 1996 and 1995 is comprised of numerous miscellaneous items,
none of which is individually significant.
1995 Compared to 1994
Oil Revenue
Oil revenue increased $3,521,000, or 40%, during 1995 as compared with 1994. The
increase in revenue is comprised of a 9% increase in price from $15.72 per
barrel in 1994 to $17.10 per barrel in 1995, combined with a 29% increase in oil
production from 558,000 barrels in 1994 to 719,000 barrels in 1995, due to
drilling and acquisitions. Because HCRC's hedged oil prices exceeded average
posted prices in 1995, the effect of hedging transactions, as described above,
was to increase HCRC's average oil price from $16.71 per barrel to $17.10 per
barrel, resulting in a $280,000 increase in revenue.
Gas Revenue
Gas revenue increased $860,000 during 1995 as compared with 1994. The increase
is comprised of a 21% increase in production from 5,865,000 mcf in 1994 to
7,071,000 mcf in 1995 partially offset by a 10% decrease in the average gas
price from $1.81 per mcf in 1994 to $1.62 per mcf in 1995. The effect of HCRC's
hedging activity was to increase HCRC's average gas price from $1.42 per mcf to
$1.62 per mcf, resulting in a $1,414,000 increase in revenue.
Pipeline and Other
Pipeline and other revenue increased by $509,000 during 1995 as compared with
1994, due to the receipt of incentive payments for a full year in 1995 versus
seven months during 1994.
Production Operating Expense
Production operating expense increased less than 2% during 1995 as compared to
1994. The increase was the result of higher taxes due to higher production,
offset by decreases in operating expenses resulting from cost savings measures
implemented during 1995 as well as the divestiture of high cost, low margin oil
wells in Kansas.
General and Administrative Expense
General and administrative expense increased by $788,000 during 1995 as compared
to 1994, primarily as a result of increased performance based compensation paid
to employees of HPI related to the successful 1995 drilling results.
Interest Expense
Interest expense increased $958,000 in 1995 as compared to 1994, primarily as a
result of increased borrowings against the Company's credit line.
-20-
<PAGE>
Depreciation, Depletion and Amortization Expense
Depreciation, depletion and amortization expense associated with proved oil and
gas properties increased $866,000 during 1995 as compared with 1994. This
increase is primarily due to higher capitalized costs during 1995 as a result of
capital expenditures incurred during the year.
Impairment of Oil and Gas Properties
HCRC recorded a property impairment during 1995 of $5,000,000 because
capitalized costs at June 30, 1995 exceeded the present value (discounted at
10%) of estimated future net revenues from proved oil and gas reserves based on
the prices received at that date of $16.50 per barrel of oil and $1.50 per mcf
of gas. An additional impairment of $4,277,000 represents the write-off of
HCRC's investment in an Indonesian project which has been abandoned. During
1994, HCRC recorded a $3,000,000 property impairment because capitalized costs
exceeded the present value (discounted at 10%) of estimated future net revenues
from proved oil and gas reserves based on prices received at December 31, 1994
of $15.34 per barrel of oil and $1.61 per mcf of gas. An additional impairment
of $1,721,000 represents the write-off of certain international projects.
Other
Other expense for 1995 and 1994 is comprised of numerous miscellaneous items,
none of which is individually significant.
-21-
<PAGE>
<TABLE>
<CAPTION>
ITEM 8 - FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX TO FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Page
FINANCIAL STATEMENTS:
<S> <C>
Independent Auditors' Report 23
Consolidated Balance Sheets at December 31, 1996 and 1995 24-25
Consolidated Statements of Operations for the years ended
December 31, 1996, 1995 and 1994 26
Consolidated Statements of Stockholders' Equity for the years
ended December 31, 1996, 1995 and 1994 27
Consolidated Statements of Cash Flows for the years ended
December 31, 1996, 1995 and 1994 28
Notes to Consolidated Financial Statements 29-41
SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (UNAUDITED) 42-45
</TABLE>
-22-
<PAGE>
INDEPENDENT AUDITORS' REPORT
To the Stockholders of Hallwood Consolidated Resources Corporation:
We have audited the consolidated financial statements of Hallwood Consolidated
Resources Corporation as of December 31, 1996 and 1995 and for each of the three
years in the period ended December 31, 1996, listed in the accompanying index at
Item 8. 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, such consolidated financial statements present fairly, in all
material respects, the financial position of Hallwood Consolidated Resources
Corporation at December 31, 1996 and 1995, and the results of its operations and
its cash flows for each of the three years in the period ended December 31, 1996
in conformity with generally accepted accounting principles.
DELOITTE & TOUCHE LLP
Denver, Colorado
February 28, 1997
-23-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CONSOLIDATED BALANCE SHEETS
(In thousands except shares)
December 31,
1996 1995
CURRENT ASSETS
<S> <C> <C>
Cash and cash equivalents $ 628 $ 1,139
Accrued oil and gas revenues 4,808 2,674
Due from affiliates 897 381
Prepaid and other assets 493 111
Current assets of affiliates 3,976 4,007
-------- -------
Total current assets 10,802 8,312
------- -------
PROPERTY, PLANT AND EQUIPMENT, at cost
Oil and gas properties (full cost method)
Proved oil and gas properties 278,581 268,152
Unproved mineral interests - domestic 1,240 571
-------- ---------
Total 279,821 268,723
Less - accumulated depreciation,
depletion, amortization and impairment (212,536) (203,290)
------- -------
Net property, plant and equipment 67,285 65,433
------- --------
OTHER ASSETS
Deferred tax asset 350
Noncurrent assets of affiliate 31 194
--------- ---------
Total other assets 381 194
-------- ---------
TOTAL ASSETS $ 78,468 $ 73,939
======= =======
<FN>
(Continued on the following page)
</FN>
</TABLE>
-24-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CONSOLIDATED BALANCE SHEETS
(In thousands except shares)
December 31,
1996 1995
CURRENT LIABILITIES
<S> <C> <C>
Accounts payable and accrued liabilities $ 2,273 $ 3,675
Current portion of contract settlement obligation 143
Current portion of long-term debt 3,750
Current liabilities of affiliates 4,826 11,696
------- -------
Total current liabilities 10,849 15,514
------- -------
NONCURRENT LIABILITIES
Contract settlement obligation 948 904
Long-term debt 16,250 12,000
Long-term obligations of affiliates 7,243 8,740
Deferred liability 117 146
--------- ---------
Total noncurrent liabilities 24,558 21,790
------- -------
Total liabilities 35,407 37,304
------- -------
COMMITMENTS AND CONTINGENCIES (NOTES 11 AND 14)
STOCKHOLDERS' EQUITY
Common stock par value $.01;
2,000,000 shares authorized;
992,514 and 1,081,763 shares
issued in 1996 and 1995, respectively 111 111
Additional paid in capital 79,990 81,730
Accumulated deficit (33,166) (41,376)
Treasury stock - 86,426 and 83,980 shares
in 1996 and 1995, respectively (3,874) (3,830)
------- -------
Stockholders' Equity - Net 43,061 36,635
------- -------
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY $ 78,468 $ 73,939
======= =======
<FN>
The accompanying notes are an integral
part of the financial statements.
</FN>
</TABLE>
-25-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands except per share)
For the Years Ended December 31,
---------------------------------
1996 1995 1994
------ ------ -----
REVENUES:
<S> <C> <C> <C>
Oil revenue $ 16,852 $ 12,294 $ 8,773
Gas revenue 16,446 11,489 10,629
Pipeline and other 1,010 1,566 1,057
Interest income 137 135 185
--------- -------- --------
34,445 25,484 20,644
------- ------ ------
EXPENSES:
Production operating expense 10,383 8,514 8,367
General and administrative expense 4,011 4,630 3,842
Interest expense 2,530 1,798 840
Depreciation, depletion and amortization 9,246 8,206 7,340
Impairment of oil and gas properties 9,277 4,721
Other 114 246 378
-------- -------- --------
26,284 32,671 25,488
------ ------ ------
INCOME (LOSS) BEFORE INCOME TAXES 8,161 (7,187) (4,844)
------- ------- -----
PROVISION (BENEFIT) FOR INCOME
TAXES:
Current 301 71 238
Deferred (350) (2,588) (2,108)
------ ------- -----
(49) (2,517) (1,870)
------- ------- -------
NET INCOME (LOSS) $ 8,210 $ (4,670) $(2,974)
====== ======= ======
NET INCOME (LOSS) PER SHARE $ 8.88 $ (4.43) $ (2.78)
======= ======= =======
WEIGHTED AVERAGE COMMON
SHARES AND COMMON SHARE
EQUIVALENTS OUTSTANDING 925 1,055 1,068
======= ======= =======
<FN>
The accompanying notes are an integral
part of the financial statements.
</FN>
</TABLE>
-26-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(In thousands)
Additional
Common Paid in Accumulated Treasury
Stock Capital Deficit Stock Total
<S> <C> <C> <C> <C> <C>
Balance, December 31, 1993 $ 111 $ 82,846 $ (33,732) $ (2,629) $ 46,596
Increase in treasury shares (33) (33)
Net loss (2,974) (2,974)
------ ----------- --------- ---------- --------
Balance, December 31, 1994 111 82,846 (36,706) (2,662) 43,589
Increase in treasury shares (1,168) (1,168)
Repurchase and retirement of
common stock (1,116) (1,116)
Net loss (4,670) (4,670)
------ ----------- --------- ---------- --------
Balance, December 31, 1995 111 81,730 (41,376) (3,830) 36,635
Increase in treasury shares (44) (44)
Repurchase and retirement of
common stock (1,750) (1,750)
Exercise of common stock
options 10 10
Net income 8,210 8,210
------ ----------- --------- ---------- --------
Balance, December 31, 1996 $ 111 $ 79,990 $ (33,166) $ (3,874) $ 43,061
==== ======== ======== ======= =======
<FN>
The accompanying notes are an integral
part of the financial statements.
</FN>
</TABLE>
-27-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
For the Years Ended December 31,
1996 1995 1994
OPERATING ACTIVITIES:
<S> <C> <C> <C>
Net income (loss) $ 8,210 $ (4,670) $ (2,974)
Adjustments to reconcile net income (loss) to net cash
provided by operating activities:
Depreciation, depletion, amortization and impairment 9,246 17,483 12,061
Deferred income tax benefit (350) (2,588) (2,108)
Noncash interest expense 83 109 149
Recoupment of take-or-pay liability (110) (168) (69)
Undistributed earnings of affiliates (5,173) (3,469) (1,023)
------- ------- -------
Cash provided by operations before working
capital changes 11,906 6,697 6,036
Changes in operating assets and liabilities provided (used) cash net of
noncash activity:
Accrued oil and gas revenues (2,134) 22 649
Due from affiliates (1,071) (381) 650
Prepaid and other assets (382) 91 3,149
Accounts payable and accrued liabilities (1,402) 1,877 (2,178)
Payable to affiliates (247) 247
--------- -------- --------
Net cash provided by operating activities 6,917 8,059 8,553
------ ------- -------
INVESTING ACTIVITIES:
Proceeds from oil and gas property sales 1,368 726 1,740
Additions to oil and gas properties (2,182) (2,188) (1,265)
Exploration and development costs incurred (7,578) (7,379) (8,556)
Refinance of Spraberry investment (6,338)
Distributions received from affiliates 1,144 1,096 626
Investment in affiliates (5,330) (64)
----------- ------- ----------
Net cash used in investing activities (13,586) (13,075) (7,519)
------- ------ -------
FINANCING ACTIVITIES:
Payments of long-term debt (2,000) (3,000)
Proceeds from long-term debt 10,000 5,000 3,000
Repurchase and retirement of common stock (1,750) (1,116)
Payments on contract settlement obligation (118) (518) (522)
Exercise of stock options 10
Other financing activities 16 10
--------- ---------
Net cash provided by (used in) financing activities 6,158 3,376 (522)
------- ------- --------
NET INCREASE (DECREASE) IN CASH AND CASH
EQUIVALENTS (511) (1,640) 512
CASH AND CASH EQUIVALENTS:
BEGINNING OF YEAR 1,139 2,779 2,267
------ ------- -------
END OF YEAR $ 628 $ 1,139 $ 2,779
====== ======= =======
<FN>
The accompanying notes are an integral
part of the financial statements.
</FN>
</TABLE>
-28-
<PAGE>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 - ORGANIZATION AND SIGNIFICANT ACCOUNTING POLICIES
Hallwood Consolidated Resources Corporation ("HCRC" or the "Company") is a
Delaware corporation engaged in the development, production, sale and
transportation of oil and gas, and in the acquisition, exploration, development
and operation of oil and gas properties. The Company's properties are primarily
located in the Rocky Mountain, MidContinent, Texas and Gulf Coast regions of the
United States. The principal objective of the Company is to pursue asset growth
through the replacement and enhancement of oil and gas reserves.
Accounting Policies
Consolidation
HCRC accounts for its interest in affiliated oil and gas partnerships and
limited liability companies using the proportionate consolidation method of
accounting. The accompanying financial statements include the activities of HCRC
and its pro rata share of the activities of Hallwood Energy Partners, L. P.
("HEP").
Property, Plant and Equipment
The Company follows the full cost method of accounting whereby all costs related
to the acquisition of oil and gas properties are capitalized in a single cost
center ("full cost pool") and are amortized over the productive life of the
underlying proved reserves using the units of production method. Proceeds from
property sales are generally credited to the full cost pool.
Capitalized costs of oil and gas properties may not exceed an amount equal to
the present value discounted at 10% of estimated future net revenues from proved
oil and gas reserves plus the cost, or estimated fair market value, if lower, of
unproved properties. Should capitalized costs exceed this ceiling, an impairment
is recognized. The present value of estimated future net revenues is computed by
applying year-end prices of oil and gas to estimated future production of proved
oil and gas reserves as of year end, less estimated future expenditures to be
incurred in developing and producing the proved reserves and assuming
continuation of existing economic conditions.
The Company does not accrue costs for future site restoration, dismantlement and
abandonment costs related to proved oil and gas properties because the Company
estimates that such costs will be offset by the salvage value of the equipment
sold upon abandonment of such properties. The Company's estimates are based upon
its historical experience and upon review of current properties and restoration
obligations.
Unproved properties are withheld from the amortization base until such time as
they are either developed or abandoned. These properties are evaluated
periodically for impairment.
During 1996, HCRC adopted Statement of Financial Accounting Standards No. 121,
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to
be Disposed Of" ("SFAS 121"). SFAS 121 provides the standards for accounting for
the impairment of various long-lived assets. Substantially all of HCRC's
long-lived assets consist of oil and gas properties which are evaluated for
impairment as described above. Therefore, the adoption of SFAS 121 did not to
have a material effect on the financial position or results of operations of
HCRC.
-29-
<PAGE>
Derivatives
HCRC has entered into numerous financial contracts to hedge the price of its oil
and natural gas. The purpose of the hedges is to provide protection against
price drops and to provide a measure of stability in the volatile environment of
oil and natural gas spot pricing. The amounts received or paid upon settlement
of these contracts are recognized as oil or gas revenue at the time the hedged
volumes are sold.
Gas Balancing
HCRC uses the sales method to account for gas balancing. Under this method, HCRC
recognizes revenue on all of its sales of production and any over-production or
under-production is recovered or repaid at a future date.
As of December 31, 1996, HCRC had a net over-produced position of 462,000 mcf
($919,000 valued at average annual prices). Current imbalances can be made up
with production from existing wells or from wells which will be drilled as
offsets to current producing wells. HCRC's oil and gas reserves as of December
31, 1996 have been reduced by 462,000 mcf in order to reflect HCRC's gas
balancing position.
Stock Split
During the fourth quarter of 1995, the stockholders of HCRC approved a
one-for-ten reverse split of HCRC's common stock, which was effective November
9, 1995. All share and per share information has been restated to reflect the
one-for-ten reverse stock split.
Cash and Cash Equivalents
All highly liquid investments purchased with an original maturity of three
months or less are considered to be cash equivalents.
Use of Estimates
The preparation of the financial statements for the Company 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 these estimates.
Computation of Net Income (Loss) Per Share
Net income (loss) per share is computed by dividing net income (loss) by the
weighted average number of common shares and common share equivalents
outstanding during the reporting period. The stock options granted during 1995
(See Note 10) are considered to be common share equivalents since January 1,
1996 because the market price of the common stock has exceeded the exercise
price of the options since that date. The number of common shares is reduced by
the number of common shares which could have been repurchased by the Company
with the proceeds from the exercise of the options (which were assumed to have
been made at the average market price of the common stock during the reporting
period).
At December 31, 1996 and 1995, the Company owns approximately 19% of the
outstanding units of HEP, which owns approximately 46% of the Company's shares;
consequently, the Company has an interest in 86,426 and 83,980 of its own shares
at December 31, 1996 and 1995, respectively. These shares are treated as
treasury stock in the accompanying financial statements.
-30-
<PAGE>
Significant Customers
Both oil and natural gas are purchased by refineries, major oil companies,
public utilities, industrial customers and other users and processors of
petroleum products. HCRC is not confined to, nor dependent upon, any one
purchaser or small group of purchasers. Accordingly, the loss of a single
purchaser, or a few purchasers, would not materially affect HCRC's business
because there are numerous purchasers in the areas in which HCRC sells its
production. However, for the years ended December 31, 1996, 1995 and 1994,
purchases by the following companies exceeded 10% of the total oil and gas
revenues of the Company:
1996 1995 1994
------ ------ -----
Koch Oil Company 23% 27% 34%
Conoco Inc. 13% 14% 15%
Scurlock Permian Corporation 14%
El Paso Field Services 11%
Environmental Concerns
The Company is continually taking actions it believes are necessary in its
operations to ensure conformity with applicable federal, state and local
environmental regulations. As of December 31, 1996, the Company has not been
fined or cited for any environmental violations which would have a material
adverse effect upon capital expenditures, earnings, cash flows or the
competitive position of the Company in the oil and gas industry.
Reclassifications
Certain reclassifications have been made to prior years' amounts to conform to
the classifications used in the current year.
NOTE 2 - OIL AND GAS PROPERTIES
The following table summarizes certain cost information related to the Company's
oil and gas activities, including its pro rata share of HEP's oil and gas
activities. The Company has no material long-term supply agreements, and all
reserves are located within the United States.
<TABLE>
<CAPTION>
For the Years Ended December 31,
1996 1995 1994
(In thousands)
<S> <C> <C> <C>
Property acquisition costs $ 2,830 $10,912 $ 1,612
Development costs 9,834 15,179 4,245
Exploration costs 989 2,472 5,190
------- ------ ------
Total $13,653 $28,563 $11,047
====== ====== ======
</TABLE>
Unproved domestic properties as of December 31, 1996 and 1995 consist primarily
of acreage in the San Juan Basin area of New Mexico.
-31-
<PAGE>
Depreciation, depletion, amortization and property impairment related to proved
oil and gas properties per equivalent barrel of production for the years ended
December 31, 1996, 1995 and 1994 was $4.17, $6.96 and $6.73, respectively.
NOTE 3 - PRINCIPAL ACQUISITIONS AND SALES
1996
On July 1, 1996, HCRC and HEP completed a transaction involving the acquisition
from Fuel Resources Development Co., a wholly owned subsidiary of Public Service
Company of Colorado, and other interest owners of their interests in 38 coal bed
methane wells located in LaPlata County, Colorado and Rio Arriba County, New
Mexico. Thirty-four of the wells, estimated to have reserves of 53 bcf, were
assigned to 44 Canyon LLC ("44 Canyon"), a special purpose entity owned by a
large east coast financial institution. The wells qualify for tax credits under
Section 29 of the Internal Revenue Code. Hallwood Petroleum, Inc. ("HPI")
manages and operates the properties on behalf of 44 Canyon. The $28.4 million
purchase price was funded by 44 Canyon through the sale of a volumetric
production payment to an affiliate of Enron Capital & Trade Resources Corp., a
subsidiary of Enron Corp., the sale of a subordinated production payment and
certain other property interests for $3.45 million to an affiliate of HCRC and
HEP, and additional cash contributed by the owners of 44 Canyon. The affiliate
of HCRC and HEP which purchased the subordinated production payment and other
property interests is owned equally by HCRC and HEP. The interests in the four
wells in Rio Arriba County were acquired directly by HCRC and HEP.
1995
On September 29, 1995, HCRC purchased 1,158,696 Class A Units of HEP having a
market value of $5,330,000 from a nominee acting on behalf of the plaintiff
class members in a class action lawsuit against HEP pursuant to the terms of an
option in the settlement of the lawsuit. The purchase of these Class A Units
represents the indirect acquisition of approximately 1.9 million equivalent
barrels of reserves.
1994
During the second quarter of 1994, HCRC and HEP formed a limited partnership
with a third party for the purpose of producing natural gas qualified for the
Section 29 tax credit under the Internal Revenue Code. A limited liability
company owned by HCRC and HEP is the general partner of the partnership. In
1994, HCRC and HEP sold a term working interest in certain wells in San Juan
County, New Mexico to the limited partnership. In November 1996, HCRC and HEP
sold to the limited partnership their 80% reversionary interest in the
properties owned by the limited partnership. As consideration for the sale, HCRC
and HEP received a production payment, an increase in incentive payments and a
90% springing reversionary interest in the properties.
In the 1994 transaction, HCRC and HEP received a cash payment totaling
$3,400,000. HCRC recorded its $1,530,000 share of the cash payment received as a
credit to oil and gas properties in the accompanying financial statements. As a
result of the 1994 and 1996 transactions, HCRC and HEP receive 97% of the cash
flow from production from the wells sold until 22.3 bcf are produced from the
wells (from November 1, 1996) and 80% of the cash flow until 31 bcf are
produced. HCRC and HEP also receive quarterly cash incentive payments equal to
34% of the Section 29 tax credit generated from the production from the wells
until 10.3 bcf are produced from the wells (from November 1, 1996), and 55%
thereafter. HCRC and HEP share in all proceeds 45% and 55%, respectively.
-32-
<PAGE>
NOTE 4 - DERIVATIVES
HCRC has entered into numerous financial contracts to hedge the price of its oil
and natural gas. HCRC does not use these hedges for trading purposes, but rather
for the purpose of providing a protection against price drops and to provide a
measure of stability in the volatile environment of oil and natural gas spot
pricing. The amounts received or paid upon settlement of these contracts is
recognized as oil or gas revenue at the time the hedged volumes are sold.
The financial contracts used by HCRC to hedge the price of its oil and natural
gas production are swaps, collars and participating hedges. Under the swap
contracts, HCRC sells its oil and gas production at spot market prices and
receives or makes payments based on the differential between the contract price
and a floating price which is based on spot market indices.
The following table provides a summary of HCRC's financial contracts:
Oil
Quantity of Production Contract
Period Hedged Floor Price
(bbls) (per bbl)
1994 178,000 $17.47
1995 220,000 16.93
1996 219,000 18.47
1997 262,000 17.88
1998 82,000 15.07
1999 23,000 15.88
From 1997 forward, between 16% and 100% of the oil volumes hedged in each year
are subject to a participating hedge whereby HCRC will receive the contract
price if the posted futures price is lower than the contract price, and will
receive the contract price plus between 25% and 75% of the difference between
the contract price and the posted futures price if the posted futures price is
greater than the contract price. From 1997 forward, between 35% and 100% of the
volumes hedged in each year are subject to a collar agreement whereby HCRC will
receive the contract price if the spot price is lower than the contract price,
the cap price if the spot price is higher than the cap price, and the spot price
if that price is between the contract price and the cap price. The cap prices
range from $17.50 to $19.35 per barrel.
Gas
Quantity of Production Contract
Period Hedged Floor Price
(mcf) (per mcf)
1994 2,196,000 $1.83
1995 1,792,000 1.84
1996 2,429,000 1.77
1997 2,413,000 1.89
1998 1,979,000 1.91
1999 1,062,000 1.67
2000 450,000 1.86
-33-
<PAGE>
From 1997 forward, between 0% and 37% of the gas volumes hedged in each year are
subject to a collar agreement whereby HCRC will receive the contract price if
the spot price is lower than the contract price, the cap price if the spot price
is higher than the cap price, and the spot price if that price is between the
contract price and the cap price.
The cap prices range from $2.78 to $2.93 per mcf.
In the event of nonperformance by the counterparties to the financial contracts,
HCRC is exposed to credit loss, but has no off-balance sheet risk of accounting
loss. The Company anticipates that the counterparties will be able to satisfy
their obligations under the contracts because the counterparties consist of
well-established banking and financial institutions which have been in operation
for many years. Certain of HCRC's hedges are secured by the lien on HCRC's oil
and gas properties which also secures HCRC's Credit Agreement described in Note
6.
NOTE 5 - RELATED PARTY TRANSACTIONS
Hallwood Petroleum, Inc. ("HPI"), an affiliated entity, manages and operates
certain oil and gas properties on behalf of other joint interest owners and the
Company. In such capacity, HPI pays all costs and expenses of operations and
distributes all revenues associated with such properties. The Company had
receivables from HPI of $897,000 and $381,000 as of December 31, 1996 and 1995,
respectively. These amounts represent revenues net of operating costs and
expenses.
The Company reimburses HPI for actual costs and expenses, which include office
rent, salaries and associated overhead for personnel of HPI engaged in the
acquisition and evaluation of oil and gas properties (technical expenditures
which are capitalized as costs of oil and gas properties) and general and
administrative and lease operating expenditures necessary to conduct the
business of the Company (nontechnical expenditures which are expensed as general
and administrative or production operating expense). Reimbursements during 1996,
1995 and 1994 were as follows (in thousands):
Technical Nontechnical
Expenditures Expenditures
1996 $823 $1,293
1995 912 1,627
1994 473 1,827
Included in the nontechnical allocation from HPI attributable to the Company's
direct interest is approximately $115,000, $111,000 and $103,000 of consulting
fees under a contract with The Hallwood Group Incorporated ("Hallwood"), an
affiliated company, during the years ended December 31, 1996, 1995 and 1994,
respectively. Also included in the nontechnical allocation is $234,000, $263,000
and $237,000 in 1996, 1995 and 1994, respectively, representing costs incurred
by Hallwood and its affiliates on behalf of the Company.
During the third quarter of 1994, HPI entered into a consulting agreement with
its Chairman of the Board to provide advisory services regarding the
international activities of its affiliates. The amount of consulting fees
allocated to the Company under this agreement is $125,000 in both 1996 and 1995
and $62,500 in 1994.
-34-
<PAGE>
NOTE 6 - DEBT
During the first quarter of 1995, the Company and its banks amended their credit
agreement to extend the term date of the line of credit to May 31, 1997. The
borrowing base is currently $23,000,000, however, the Company's borrowings are
presently limited to the bank's commitment level of $22,000,000. As of December
31, 1996, the Company has borrowed $20,000,000 against the credit line. HCRC's
borrowing base is also reduced by outstanding contract settlement debt of
$948,000; therefore, unused borrowing base totaled $2,052,000 at February 28,
1997.
Borrowings against the credit line bear interest, at the option of the Company,
at either (i) the banks' Certificate of Deposit rate plus 1.875%, (ii) the
Euro-Dollar rate plus 1.75% or (iii) the higher of the prime rate of Morgan
Guaranty Trust or the sum of one-half of 1% plus the Federal funds rate, plus
.75%. At December 31, 1996 the applicable interest rate was 7.7%. Interest is
payable at least quarterly, and quarterly principal payments of $1,250,000, as
adjusted for the borrowings subsequent to year end, commence May 31, 1997. HCRC
intends to extend the maturity date of its credit line prior to the commencement
of the amortization period. The credit facility is secured by a first lien on
approximately 80% of the Company's oil and gas properties.
As of December 31, 1996, the Company's five year debt maturity schedule is as
follows:
(In thousands)
1997 $ 3,750
1998 5,000
1999 5,000
2000 5,000
2001 1,250
-------
20,000
Less: Current maturities of long-term debt 3,750
------
Long-term debt balance at December 31, 1996 $16,250
======
HCRC has entered into contracts to hedge its interest rate payments on
$7,000,000 of its debt through 1996, $10,000,000 for each of 1997 and 1998 and
$5,000,000 for each of 1999 and 2000. HCRC does not use the hedges for trading
purposes, but rather for the purpose of providing a measure of predictability
for a portion of HCRC's interest payments under its debt agreement, which has a
floating interest rate. In general, it is HCRC's goal to hedge 50% of the
principal amount of its debt for the next two years and 25% for each year of the
remaining term of the debt. HCRC has entered into four hedges, of which one is
an interest rate collar pursuant to which it pays a floor rate of 7.55% and a
ceiling rate of 9.85% and the others are interest rate swaps with fixed rates
ranging from 5.75% to 6.57%. The amounts received or paid upon settlement of
these transactions are recognized as interest expense at the time the interest
payments are due.
NOTE 7 - CONTRACT SETTLEMENT OBLIGATION
In March 1989, the Company received $2,877,000 as a recoupable take-or-pay
settlement on a contract with a gas pipeline. The settlement was recoupable
monthly in cash or gas volumes, from April 1992 through March 1996 with a
balloon payment due during the first quarter of 1998. A liability has been
recorded equal to the present value of the settlement discounted at 10.68%,
HCRC's estimated borrowing cost in 1989. The Company also repaid $640,000 which
represented the balance of suspended payments to the pipeline for previous
years, in equal monthly installments of $13,329 through March 1996. This amount
was previously recorded as an offset to the full cost pool at the time the
contract was initially abrogated by the pipeline. As payment of this obligation
was made, it was charged to the full cost pool.
-35-
<PAGE>
At December 31, 1996, the long-term contract settlement balance consists of a
payment of $1,044,000 due in March 1998, net of unaccreted discount of $96,000.
NOTE 8 - STATEMENT OF CASH FLOWS
Cash paid for interest during 1996, 1995 and 1994 was $1,374,000, $625,000 and
$361,000, respectively. Cash paid for income taxes during 1996 and 1995 was
$185,000 and $122,000, respectively. A refund of taxes of $285,000 was received
during 1994.
NOTE 9 - INCOME TAXES
The following is a summary of the income tax provision (benefit):
For the Years
Ended December 31,
1996 1995 1994
(In thousands)
State $ 236 $ 62 $ 176
Federal - Current 65 9 62
Deferred (350) (2,588) (2,108)
---- ------ ------
Total $ (49) $(2,517) $(1,870)
==== ====== ======
Reconciliations of the expected tax at the statutory tax rate to the effective
tax are as follows:
For the Years
Ended December 31,
1996 1995 1994
(In thousands)
Expected tax expense (benefit) at the
statutory rate $2,775 $(2,443) $(1,647)
State taxes net of federal benefit 156 41 116
Change in valuation allowance (3,739)
Other 759 (115) (339)
------ ------- -------
Effective tax benefit $ (49) $(2,517) $(1,870)
======= ====== ======
-36-
<PAGE>
Deferred income taxes reflect the net tax effects of temporary differences
between the carrying amounts of assets and liabilities for financial reporting
purposes and the amounts used for income tax purposes. The tax effects of
significant items comprising the Company's deferred tax assets and liabilities
as of December 31, 1996 and 1995 are as follows:
1996 1995
------ -----
Deferred tax assets:
Net operating loss carryforward $3,606 $ 4,647
Capital loss carryforward 1,688 1,753
Temporary differences between
book and tax basis of property 1,235 2,745
Other 773
-------- ------
Total 6,529 9,918
Valuation allowance (6,179) (9,918)
------ ------
Net deferred tax asset $ 350 $
======= ========
The Company's net operating loss carryforwards expire between 2007 and 2010.
NOTE 10 - EMPLOYEE INCENTIVE PLANS
Every year beginning in 1992, the Company's Board of Directors has adopted an
incentive plan. Each year the Board of Directors determines the percentage of
HCRC's interest in the cash flow from certain wells drilled, recompleted or
enhanced during the year allocated to the incentive plan for that year. The
specified percentage was 2.4% for 1996, 1.4% for domestic wells for 1995 and 1%
for domestic wells for 1994. In 1994 and 1995, HCRC also had an international
incentive plan and the percentage interest in cash flow for that plan was 3%.
Beginning in 1996, the domestic and international plans were combined. The
specified percentage of cash flow is then allocated among certain key employees
who are participants in the plan for that year. Each award under the plan (with
regard to domestic properties) represents the right to receive for five years a
portion of the specified share of the cash flow attributable to qualifying wells
included in the plan for that year. In the sixth year after the award, the
participants are each paid a share of an amount equal to a specified percentage
(80% for 1996 and 1995 and 40% for 1994) of the remaining net present value of
the qualifying wells, and the award for that year terminates. The expenses
attributable to the plans were $119,000 in 1996, $147,000 in 1995 and $67,000 in
1994 and are included in general and administrative expense in the accompanying
financial statements.
During 1995, the Company adopted a stock option plan covering 53,000 shares of
Common Stock and granted options for all of the shares under the plan. The
options were granted effective July 1, 1995 at an exercise price of $20.00 per
share, which was equal to the fair market value of the Common Stock on the day
preceding the date of grant. The options expire on July 1, 2005, unless sooner
terminated pursuant to the provisions of the plan. The options are exercisable
one-third on July 1, 1995, an additional one-third on July 1, 1996, and the
remaining one-third on July 1, 1997. During December 1996, 500 options were
exercised.
-37-
<PAGE>
A summary of HCRC's Option Plan as of December 31, 1996 and 1995 and the changes
therein during the years then ended on those dates is presented below:
<TABLE>
<CAPTION>
1996 1995
------ ----
Exercise Exercise
Shares Price Shares Price
<S> <C> <C> <C> <C>
Outstanding at beginning of year 53,000 $20.00
Granted 53,000 $20.00
Exercised 500 20.00
------- -----
Outstanding at end of year 52,500 $20.00 53,000 $20.00
====== ===== ====== =====
Options exercisable at year end 34,833 17,667
====== ======
</TABLE>
The Company has adopted the disclosure-only provisions of Statement of Financial
Accounting Standards No. 123, "Accounting for Stock-Based Compensation" ("SFAS
123"). Accordingly, no compensation cost has been recognized for the Option
Plan. Had compensation expense for the Option Plan been determined based on the
fair value at the grant date for the options awarded in 1995 consistent with the
provisions of SFAS 123, HCRC's net income (loss) and net income (loss) per share
would have been reduced to the pro forma amounts indicated below:
1996 1995
------ -----
Net income (loss): as reported $8,210,000 $(4,670,000)
pro forma 7,975,000 (5,078,000)
Net income (loss) per share: as reported $8.88 $(4.43)
pro forma 8.68 (4.81)
The fair value of the options for disclosure purposes was estimated on the date
of the grant using the Black-Scholes Model with the following assumptions:
Expected dividend yield 0%
Expected price volatility 40%
Risk-free interest rate 6.2%
Expected life of options 10 years
NOTE 11 - COMMITMENTS
The Company is guarantor of 40% of the obligation under the Denver, Colorado
office lease which is in the name of HPI. HEP is guarantor of the remaining 60%
of the obligation. HPI leases 41,000 square feet for approximately $600,000 per
year. The lease expires in 1999.
-38-
<PAGE>
NOTE 12 - ODD LOT REPURCHASE
The Company made an offer to repurchase odd lot holdings of 99 or fewer shares
from its stockholders of record as of November 30, 1995. The offer was initially
for the period from November 30, 1995 through January 5, 1996 and was
subsequently extended through January 26, 1996. The Company repurchased a total
of 98,869 shares through the January 26, 1996 closing date. The repurchase price
was $24.09 per share.
On April 1, 1996, HCRC made another offer to purchase holdings of 99 or fewer
shares from its stockholders of record as of March 25, 1996. The offer was for
the period from April 1, 1996 through May 3, 1996. The Company repurchased a
total of 25,930 shares at a purchase price of $34.00 per share. HCRC resold
12,965 of these shares to HEP at the price paid by HCRC for such shares.
NOTE 13 - INVESTMENT IN AFFILIATED ENTITIES
HCRC accounts for its 19% investment in HEP and, in 1995, its 60% investment in
Hallwood Spraberry Drilling Company, L.L.C. ("HSD") using the pro rata method of
accounting. The following presents summarized financial information for HEP as
of and for the years ended December 31, 1996, 1995 and 1994, and for HSD as of
and for the year ended December 31, 1995, (its first year of operations). HCRC
assumed direct ownership of the properties previously held by HSD effective
April 1, 1996.
<TABLE>
<CAPTION>
HEP 1996 1995 1994
--- ------ ------ -----
(In thousands)
<S> <C> <C> <C>
Current assets $ 20,380 $ 18,503 $ 14,670
Noncurrent assets 102,412 106,649 121,611
Current liabilities 21,735 22,866 24,834
Noncurrent liabilities 33,506 41,672 29,721
Minority interest 3,336 3,042 2,923
Revenue 51,066 43,780 44,482
Net income (loss) 15,726 (9,031) (10,093)
HSD 1995
(In thousands)
Current assets $ 629
Noncurrent assets 14,243
Current liabilities 1,900
Noncurrent liabilities 11,000
Revenue 4,194
Net income 1,631
</TABLE>
No other individual entity in which HCRC owns an interest comprises in excess of
10% of the revenues, net income or assets of HCRC.
-39-
<PAGE>
NOTE 14 - LEGAL PROCEEDINGS
On April 23, 1992, a lawsuit was filed in the Chancery Court for New Castle
County, Delaware, styled Tappe v. Hallwood Consolidated Resources Corporation,
Hallwood Consolidated Partners, L. P., Hallwood Oil and Gas, Inc., Hallwood
Energy Partners, L. P., and Hallwood Petroleum, Inc. (C. A. No 12536). The
lawsuit seeks to rescind the conversion of Hallwood Consolidated Partners, L.P.
("HCP") into the Company ("Conversion") and to recover damages in unspecified
amounts. The plaintiff also seeks class certification to represent similarly
situated HCP unitholders. In general, the suit alleges that the defendants
breached fiduciary duties to HCP unitholders by, among other things, proposing
allocation of common stock in the Conversion on a basis that the plaintiff
alleges is unfair, failing to require that the allocation be approved by an
independent third party, causing the costs of proposing the Conversion to be
borne indirectly by the partners of HCP whether or not the Conversion was
completed, and failing to disclose certain matters in the Consent
Statement/Prospectus soliciting consents to the Conversion. The defendants
believe that they fully considered and disclosed all material information in
connection with the Conversion, and they believe that the suit is without merit.
HCRC plans to vigorously defend this case, but because of its early stages,
cannot predict the outcome of this matter or any possible effect an adverse
outcome might have.
The Company is involved in other legal proceedings and claims which have arisen
in the ordinary course of its business and have not been finally adjudicated.
The Company believes that its liability, if any, as a result of such proceedings
and claims will not materially affect its financial condition or operations.
NOTE 15 - ESTIMATED FAIR VALUE OF FINANCIAL INSTRUMENTS
The following disclosure of the estimated fair value of financial instruments is
made in accordance with the requirements of SFAS No. 107, "Disclosures about
Fair Value of Financial Instruments." The estimated fair value amounts have been
determined by the Company, using available market information and appropriate
valuation methodologies. However, considerable judgment is necessarily required
in interpreting market data to develop the estimates of fair value. Accordingly,
the estimates presented herein are not necessarily indicative of the amounts
that the Company could realize in a current market exchange. The use of
different market assumptions and/or estimation methodologies may have a material
effect on the estimated fair value amounts.
December 31, 1996
Carrying Estimated Fair
Amount Value
(In thousands)
Liabilities:
Interest rate hedge contracts $ -0- $ 135
Oil and gas hedge contracts -0- 14,100
Current portion of long-term debt 3,750 3,750
Long-term debt 16,250 16,250
Contract settlement 948 953
The estimated fair value of the interest rate hedge contracts is computed by
multiplying the difference between the year end interest rate and the contract
interest rate by the amounts under contract. This amount has been discounted
using an interest rate that could be available to the Company.
The estimated fair value of the oil and gas hedge contracts is determined by
multiplying the difference between year end oil and gas prices and the hedge
contract price by the quantities under contract. This amount has been discounted
using an interest rate that could be available to the Company.
-40-
<PAGE>
Long-term debt is carried in the accompanying balance sheets at an amount which
is a reasonable estimate of its fair value.
The estimated fair value of contract settlement is determined using interest
rates that could be available to the Company for similar instruments with
similar terms.
The fair value estimates presented herein are based on pertinent information
available to management as of December 31, 1996. Although management is not
aware of any factors that would significantly affect the estimated fair value
amounts, such amounts have not been comprehensively revalued for purposes of
these financial statements since that date, and current estimates of fair value
may differ significantly from the amounts presented herein.
-41-
<PAGE>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION
(Unaudited)
The following reserve quantity and future net cash flow information for the
Company represents proved reserves which are located in the United States. The
reserve estimates presented have been prepared by in-house petroleum engineers,
and a majority of these reserves has been reviewed by independent petroleum
engineers. The determination of oil and gas reserves is based on estimates which
are highly complex and interpretive. The estimates are subject to continuing
change as additional information becomes available.
The standardized measure of discounted future net cash flows provides a
comparison of the Company's proved oil and gas reserves from year to year. Under
the guidelines set forth by the Securities and Exchange Commission, the
calculation is performed using year end prices. At December 31, 1996, oil and
gas prices averaged $23.96 per bbl of oil and $3.75 per mcf of gas for the
Company, including its interest in HEP. Future production costs are based on
year end costs and include severance taxes. The present value of future cash
inflows is based on a 10% discount rate. The reserve calculations using these
December 31, 1996 prices result in 7.2 million bbls of oil, 65 billion cubic
feet of gas and a standardized measure of $134,000,000. This standardized
measure is not necessarily representative of the market value of the Company's
properties.
HCRC's standardized measure of future net cash flows has been decreased by
$14,100,000 at December 31, 1996 for the effect of its hedge contracts. This
amount represents the difference between year end oil and gas prices and the
hedge contract prices multiplied by the quantities subject to contract,
discounted at 10%.
-42-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
RESERVE QUANTITIES
(Unaudited)
(In thousands)
Gas Oil
(Mcf) (Bbls)
Proved Reserves:
<S> <C> <C>
Balance, December 31, 1993 44,889 3,579
Extensions and discoveries 4,900 1,201
Revisions of previous estimates (1,459) 753
Sales of reserves in place (302) (171)
Purchases of reserves in place 761 155
Production (5,865) (558)
------ ------
Balance, December 31, 1994 42,924 4,959
Extensions and discoveries 7,548 2,761
Revisions of previous estimates 2,790 131
Sales of reserves in place (52) (151)
Purchases of reserves in place 7,533 664
Production (7,071) (719)
------ ------
Balance, December 31, 1995 53,672 7,645
Extensions and discoveries 1,947 491
Revisions of previous estimates 7,701 (28)
Sales of reserves in place (1,627) (160)
Purchases of reserves in place 11,488 70
Production (8,280) (837)
------ ------
Balance, December 31, 1996 64,901 7,181
====== =====
Proved Developed Reserves:
Balance, December 31, 1994 39,637 3,848
====== =====
Balance, December 31, 1995 49,854 6,657
====== =====
Balance, December 31, 1996 63,044 6,431
====== =====
</TABLE>
-43-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
(Unaudited)
(In thousands)
December 31,
-------------
1996 1995 1994
------ ------ -----
<S> <C> <C> <C>
Future sales $413,000 $243,000 $151,000
Future production and development costs (158,000) (106,000) (69,000)
Provision for income tax (30,000) (4,000) (1,000)
-------- -------- --------
Future cash flows 225,000 133,000 81,000
10% discount to present value (91,000) (48,000) (29,000)
--------- -------- --------
Standardized measure of discounted future
net cash flows $134,000 $ 85,000 $ 52,000
======= ======== ========
</TABLE>
-44-
<PAGE>
<TABLE>
<CAPTION>
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
CHANGES IN THE STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
(Unaudited)
(In thousands)
For the Years Ended December 31,
1996 1995 1994
<S> <C> <C> <C>
Standardized measure of discounted future
net cash flows at beginning of year $ 85,000 $ 52,000 $ 54,000
Sales of oil and gas produced, net of
production costs (22,915) (15,268) (11,035)
Net changes in prices and production costs 46,516 11,325 (5,459)
Extensions and discoveries net of future
production and development costs 7,011 22,133 9,220
Changes in estimated future development costs (8,509) (16,151) (6,242)
Development costs incurred 9,834 15,179 4,245
Revisions of previous quantity estimates 10,802 3,280 2,330
Purchase of reserves in place 17,061 10,571 1,288
Sale of reserves in place (3,707) (879) (1,011)
Accretion of discount 8,513 5,200 5,400
Net change in income taxes (15,332) (2,121) 167
Changes in production rates and other (274) (269) (903)
--------- -------- --------
Standardized measure of discounted
future net cash flows at end of year $134,000 $ 85,000 $ 52,000
======= ======= =======
</TABLE>
-45-
<PAGE>
ITEM 9 - DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURES
None.
PART III
ITEM 10 - DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
The information required by this item will be included in the
definitive proxy statement of HCRC relating to HCRC's 1997
Annual Meeting of Shareholders to be filed with the SEC
pursuant to Regulation 14A, which information is incorporated
herein by reference.
ITEM 11 - EXECUTIVE COMPENSATION
The information required by this item will be included in the
definitive proxy statement of HCRC relating to HCRC's 1997
Annual Meeting of Shareholders, to be filed with the SEC
pursuant to Regulation 14A, which information is incorporated
herein by reference.
ITEM 12 - SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information required by this item will be included in the
definitive proxy statement of HCRC relating to HCRC's 1997
Annual Meeting of Shareholders, to be filed with the SEC
pursuant to Regulation 14A, which information is incorporated
herein by reference.
ITEM 13 - CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item will be included in the
definitive proxy statement of HCRC relating to HCRC's 1997
Annual Meeting of Shareholders, to be filed with the SEC
pursuant to Regulation 14A, which information is incorporated
herein by reference.
PART IV
ITEM 14 - EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
Financial Statements and Financial Statement Schedules
See Index at Item 8
Reports on Form 8-K
No reports on Form 8-K were filed during the quarter ended
December 31, 1996.
-46-
<PAGE>
Exhibits
(1) 3.1 Restated Certificate of Incorporation of HCRC, as amended
through January 21, 1992
(1) 3.2 Bylaws of HCRC
(2) 3.3 Amendment to Bylaws of HCRC
(3) 3.4 Certificate of Amendment of Restated Certificate of
Incorporation dated November 9, 1995.
(1) 10.1 Agreement of Limited Partnership of Hallwood Consolidated
Partners, L.P.(originally, agreement of HCP Acquisition, L. P.)
(1) 10.5 Management Agreement between Hallwood Petroleum, Inc. and HCRC
(4) 10.7 Amended and Restated Credit Agreement dated as of March 31,1995
among HCRC and the Banks listed therein.
(4) 10.8 Extension of Management Agreement between HCRC and Hallwood
Petroleum, Inc. dated May 1, 1995.
* (4) 10.9 Domestic Incentive Plan between HCRC and Hallwood Petroleum,
Inc. dated January 14, 1993.
* (5) 10.10 1995 Stock Option Plan
* (5) 10.11 1995 Stock Option Loan Program
(6) 10.12 Amendment No. 2 to Amended and Restated Credit Agreement
(7) 21 Subsidiaries of Registrant
23.1 Consent of Deloitte & Touche LLP
(1) Incorporated by reference to the Registrant's Registration
Statement No. 33-45729 on Form S-4 filed on February 14, 1992.
(2) Incorporated by reference to the Annual Report on Form 10-K for
the year ended December 31, 1992.
(3) Incorporated by reference to the Quarterly Report on Form 10-Q
for the quarter ended September 30, 1995.
(4) Incorporated by reference to the Quarterly Report on Form 10-Q
for the quarter ended March 31, 1995.
(5) Incorporated by reference to the Quarterly Report on Form 10-Q
for the quarter ended June 30, 1995.
(6) Incorporated by reference to the Quarterly Report on Form 10-Q
for the quarter ended March 31, 1996.
(7) Incorporated by reference to the Annual Report on Form 10-K for
the year ended December 31, 1995.
* Designates management contract or compensatory plan or arrangement.
-47-
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange
Act of 1934, the registrant has duly caused this report to be signed on its
behalf by the undersigned, thereunto duly authorized.
HALLWOOD CONSOLIDATED RESOURCES CORPORATION
Date: March 20, 1997 By: /s/William L. Guzzetti
---------------------------------- -----------------------
William L. Guzzetti
President and Director
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.
<TABLE>
<CAPTION>
Signature Capacity Date
<S> <C> <C>
/s/Anthony J. Gumbiner Chairman of the Board and March 20, 1997
- ----------------------------------- --------------
Anthony J. Gumbiner Director
Director March 20, 1997
Brian M. Troup
Director March 20, 1997
John R. Isaac, Jr.
/s/Jerry A. Lubliner Director March 20, 1997
Jerry A. Lubliner
/s/Hamilton P. Schrauff Director March 20, 1997
Hamilton P. Schrauff
/s/Bill M. Van Meter Director March 20, 1997
- ------------------------------------- --------------
Bill M. Van Meter
/s/Robert S. Pfeiffer Vice President - March 20, 1997
- --------------------------------------- --------------
Robert S. Pfeiffer Chief Financial Officer
(Principal Accounting Officer)
</TABLE>
-48-
<PAGE>
EXHIBIT 23.1
-49-
<PAGE>
EXHIBIT 23.1
INDEPENDENT AUDITORS' CONSENT
We consent to the incorporation by reference in Registration Statement No.
333-1154 of Hallwood Consolidated Resources Corporation on Form S-8 of our
report dated February 28, 1997, appearing in this Annual Report on Form 10-K of
Hallwood Consolidated Resources Corporation for the year ended December 31,
1996.
DELOITTE & TOUCHE LLP
Denver, Colorado
March 20, 1997
-50-
<PAGE>
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
This schedule contains summary financial information extracted from Form 10-K
the year ended December 31, 1996 for Hallwood Consolidated Resources Corporation
and is qualified in its entirety by reference to such Form 10-K.
</LEGEND>
<CIK> 0000883953
<NAME> Hallwood Consolidated Resources Corporation
<MULTIPLIER> 1,000
<S> <C>
<PERIOD-TYPE> 12-mos
<FISCAL-YEAR-END> Dec-31-1996
<PERIOD-END> Dec-31-1996
<CASH> 628
<SECURITIES> 0
<RECEIVABLES> 5,705
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 10,802
<PP&E> 279,821
<DEPRECIATION> 212,536
<TOTAL-ASSETS> 78,468
<CURRENT-LIABILITIES> 10,849
<BONDS> 0
0
0
<COMMON> 111
<OTHER-SE> 43,061
<TOTAL-LIABILITY-AND-EQUITY> 78,468
<SALES> 34,308
<TOTAL-REVENUES> 34,445
<CGS> 0
<TOTAL-COSTS> 10,383
<OTHER-EXPENSES> 114
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 2,530
<INCOME-PRETAX> 8,161
<INCOME-TAX> (49)
<INCOME-CONTINUING> 8,210
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 8,210
<EPS-PRIMARY> 8.88
<EPS-DILUTED> 8.88
</TABLE>
